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Home My WebLink About2023-03-24 IMC Agenda and docs INTERTIE MANAGEMENT COMMITTEE (IMC) REGULAR MEETING AGENDA March 24, 2023 9:00 AM Alaska Energy Authority Board Room 813 W Northern Lights Blvd, Anchorage, AK 99503 To participate dial 1-888-585-9008 and use code 212-753-619# 1. CALL TO ORDER 2. ROLL CALL FOR COMMITTEE MEMBERS 3. PUBLIC ROLL CALL 4. PUBLIC COMMENTS 5. AGENDA APPROVAL 6. APPROVAL OF PRIOR MINUTES – January 20, 2023 7. NEW BUSINESS A. FY24 IMC Budget 8. OLD BUSINESS A. Railbelt Synchro-phasor Project B. Intertie Vegetation Management Plan 9. COMMITTEE REPORTS A. Budget to Actuals Report B. IOC Report C. Operator’s Report 10. MEMBERS COMMENTS 11. NEXT MEETING DATE – May 5, 2023 12. ADJOURNMENT Alaska Intertie FY24 Proposed Budget FY23 Approved Proposed FY21 FY22 ACTUALS FY23 FY24 Actual Actual @12/31/22 Budget Budget REVENUES GVEA 1,942,988 2,075,721 956,242 2,659,181 3,628,467 CEA 290,065 265,259 277,769 405,435 456,155 MEA 460,479 413,239 256,628 440,368 639,567 INTEREST 903 1,668 18,440 TOTAL REVENUES 2,694,435 2,755,887 1,509,078 3,504,985 4,724,189 EXPENSES FERC 562 - Station Operation Expenses GVEA - Substation Electricity Usage 9,382 45,889 2,677 - - Per GVEA 9,382 45,889 2,677 - - FERC 566 - Miscellaneous Transmission Expense Private Line Telephone Service for AKI SCADA (GVEA)5,556 5,556 3,010 10,000 - Per GVEA Cell Phone Comm. Svc for Weather Monitoring (Verizon)11,904 12,025 4,980 13,000 13,000 Per AEA SLMS Support and Intertie Ground Patrol 98,540 154,947 25,601 140,000 175,000 Per AEA Misc Studies as needed (Cyber Security Study) - - - - - 116,000 172,528 33,591 163,000 188,000 FERC 567 - Transmission Expenses - Rents Rents - Alaska Railroad 700 700 1,500 700 1,000 Fixed MEA - Talkeetna Storage 7,200 7,200 3,600 7,200 7,200 Fixed Equipment Return - 375 102 - PSSE key replacement - - - - 7,900 8,275 5,202 7,900 8,200 FERC 569 Maintenance of Structures MEA - Maintenance of Structures - - - - - Per MEA MEA - Re-insulate 20 dead-end structures 420,000 MEA - Re-insulate 30 tangent structures 320,000 - - - - - - - - 740,000 FERC 570 - Maintenance of Station Equipment GVEA - Healy, Cantwell, Goldhill 154,917 63,163 111,019 75,000 125,000 Per GVEA GVEA - SCADA Maintenance Healy, Cantwell, Gold Hill - - - 5,000 - Per GVEA GVEA - Replace Healy Substation Breaker B17 - - - - - Per GVEA GVEA - Healy, Teeland, Goldhill Dampers - - - - - Per GVEA GVEA - Healy and Goldhill Digital Fault Recorders 53,255 - - Per IOC GVEA - Healy SVC Fire Alarm Panel Replacement - - - - - Per GVEA GVEA - Gold Hill SVC Fire Alarm Panel Replacement - - - - - Per GVEA GVEA - Gold Hill SVC Cooling 460 - - Per GVEA GVEA - Cantwell Install Breakers or Load Break Switches - 182,606 30,434 156,000 156,000 Per GVEA GVEA - Cantwell 4S2 Switch Repair - - - - - Per GVEA GVEA - Replace Battery Healy SVC - - - - - Per GVEA GVEA - Replace Battery Goldhill SVC - - - - - Per GVEA GVEA - Perform Maintenance, repaint Reactors Healy SVC Yard 145,494 - - - - Per GVEA GVEA - Perform Maintenance, repaint Reactors Gold Hill SVC Yard 7,452 4,472 80,000 - Per GVEA GVEA - Mobile Substation Site - - - - - Per GVEA GVEA - Cantwell RTU, Recloser, & Transformer Protection replacement - - - - - Per GVEA GVEA - Recloser Control Replacement - - - - - Per GVEA GVEA - Transformer Protection Upgrades - - - - - Per GVEA GVEA - Dissolved Gas Monitoring Gold Hill & Healy - - - - - Per GVEA GVEA - Cantwell Standby Generator Replacement 29,016 - Per GVEA GVEA - SVC Intertie Trust Fund Eligible Expenses - - - - - Per GVEA SVC ALASKA INTERTIE TRUST FUND - - - - - Per IMC CEA - AK Intertie Yard - - - - - CEA - Teeland Substation Communication - - 5,000 5,000 Per CEA CEA - Teeland Substation 183,401 115,365 50,548 168,200 170,000 Per CEA MEA - Douglas Substation 26,115 - - - - Per MEA MEA - Douglas Substation 138 kV BKR Inspections 25,000 25,000 Per MEA GVEA - Douglas Substation OOS relaying and communications - - - - - Per GVEA CEA - Telecomm Support (Douglas, Teeland, Anc-Fbks Leased Circuits)- 1,742 - - - Per CEA 538,943 424,043 196,472 514,200 481,000 FERC 571 - Maintenance of Overhead Lines GVEA - Northern Maintenance 68,204 107,641 44,048 100,000 150,000 Per GVEA GVEA-Private Line Telephone Service - - 20,961 - GVEA - Northern ROW Clearing 36,721 68,882 - 300,000 550,000 Per GVEA GVEA - Landing Pads - - - 75,000 Per GVEA GVEA - Re-level Structures & Adjust Guys - - - 80,000 Per GVEA GVEA - Repair Tower 504 Foundation - - Per GVEA GVEA - Repair Tower 537 Foundation - GVEA - Repair Tower 539 Foundation - GVEA - Repair Tower 569 Foundation - - Per GVEA GVEA - Repair Tower 531 Foundation 50,000 150,000 GVEA - Repair Tower 532 Foundation 50,000 150,000 GVEA - Repair Tower 748 - - - - Per GVEA GVEA - Repair Tower 692 - - - - Per GVEA MEA - Special Patrols [Incl Helicopter Inspections]599 488 10,000 - Per MEA MEA - Southern Maint (Incl Ground and Climbing Inspect)138,199 191,358 - 140,000 140,000 Per MEA MEA - Southern ROW Clearing 228,413 168,367 170,150 500,000 500,000 Per MEA MEA - Southern ROW Remote Sensing and Analysis 125,000 MEA - TWR 195 Repair Monitoring - - - - Per MEA MEA - Equipment Repair and Replacement 780,866 76,494 - 684,000 350,000 Per MEA 1,252,403 613,341 235,647 1,834,000 2,270,000 FERC 924 - Property Insurance AK Intertie - Insurance 38,773 37,133 - 25,000 37,000 Per AEA (Gen Liab/Comm Umbrella) & MEA (incl Aviation) Page 1 of 4 38,773 37,133 - 25,000 37,000 Intertie Operating Costs Total 1,963,401 1,301,209 473,589 2,544,100 3,724,200 FERC 570 - Maintenance of Station Equipment MEA - Replace Protective Relay Schemes Douglas - - - - - Per MEA - - - - - Intertie Cost of Improvements Total - - - - - FERC 920 - AEA Administrative Costs Personal Services, Travel and Other Costs 210,409 235,608 25,891 200,000 250,000 Per AEA 210,409 235,608 25,891 200,000 250,000 FERC 920 - IMC Administrative Costs IMC Administrative Costs (Audit, meetings, legal)30,890 29,276 16,466 20,000 - Per IMC Chair 30,890 29,276 16,466 20,000 - FERC 566 - Miscellaneous Transmission Expense Misc Studies: System Reserves Study (IBR), PSS/E maint, 230 kV Upgrade System Impact Study 186,675 145,327 (27,000) 216,000 466,000 per IOC LIDAR study (complete lidar, vegetation, PLS CADD file with drawings, structure/foundation movement, infrared, and imaging) 226,125 - - Asset management plan 50,000 - per IOC Proposed Synchrophaser system 230,000 - per IOC Unbalanced Snow Load mitigation analysis and recommendations 50,000 - Reliability Standards Update (Hdale Inc.)- - - - per IOC 412,800 145,327 (27,000) 546,000 466,000 Intertie Administration Costs Total 654,099 410,211 15,357 766,000 716,000 TOTAL EXPENSE 2,617,500 1,711,420 488,945 3,310,100 4,440,200 SURPLUS (SHORTAGE) 76,935 1,044,468 1,020,133 194,885 283,989 Page 2 of 4 Alaska Intertie FY24 Proposed Budget True up to Contract GVEA MEA CEA TOTAL USAGE CAPACITY ADMIN CASH FLOW MONTH Value MWH MWH MWH MWH GVEA MEA CEA GVEA MEA CEA GVEA | MEA | CEA TOTALS Jul 11,500 1,993 0 13,493 $142,255 $24,653 $0 $307,320 $89,832 $217,488 $59,667 $841,215 Aug 13,600 2,034 0 15,634 $168,232 $25,161 $0 $59,667 $253,059 Sep 14,050 1,972 0 16,022 $173,799 $24,394 $0 $59,667 $257,859 Oct 23,500 2,036 0 25,536 $290,695 $25,185 $0 $59,667 $375,547 Nov 25,190 2,273 0 27,463 $311,600 $28,117 $0 $59,667 $399,384 Dec 24,990 2,494 0 27,484 $309,126 $30,851 $0 $59,667 $399,644 Jan 25,470 2,495 0 27,965 $315,064 $30,863 $0 $59,667 $405,594 Feb 24,740 2,043 0 26,783 $306,034 $25,272 $0 $59,667 $390,972 Mar 21,230 2,158 0 23,388 $262,615 $26,694 $0 $59,667 $348,976 Apr 13,470 1,943 0 15,413 $166,624 $24,035 $0 $59,667 $250,325 May 20,380 1,871 0 22,251 $252,101 $23,144 $0 $59,667 $334,912 Jun 31,070 1,835 0 32,905 $384,336 $22,699 $0 $59,667 $466,702 TOTAL 0 249,190 25,147 0 274,337 $3,082,480 $311,068 $0 $307,320 $89,832 $217,488 $716,000 $4,724,189 Total Energy:$3,393,549 Total Capacity :$614,640 274,337 MWH 251,476 MWH 204,984 MWH TOTAL MWH REVENUE $4,724,189 O&M BUDGET - Operating 3,724,200 O&M BUDGET - Administrative 716,000 UTILITY FY 23 TOTAL O&M BUDGET 4,440,200 MEA 29.20% 22.80 MW SURPLUS (SHORTAGE) $283,989 CEA 70.80% 55.20 MW GVEA 100.00% 78.00 MW Annual Participant Administrative Contribution 238,666.67 156.0 Monthly Contribution per Participant 19,888.89 Usage Rate per KWH 0.01237$ Capacity Rate $3.94 Section 7.2.2 MINIMUM USAGE CONTRACT VALUE ALASKA INTERTIE FISCAL YEAR 2024 ENERGY PROJECTION TOTAL INTERTIE PROJECTED ENERGY USAGE Usage estimate reduced by 1/12 of Total for rate calculations Page 3 of 4 Alaska Intertie FY24 Proposed Budget Annual System Demand 19-20 20-21 21-22 22-23 3 YR AVG. SOUTHERN UTILITY PARTICIPANTS (MW) CEA 364.5 366.0 349.8 343.8 353.2 MW DRAFT APPROVED APPROVED APPROVED APPROVED APPROVED MEA 137.0 145.0 146.0 147.0 146.0 MW 6/30/2024 6/30/2023 6/30/2022 6/30/2021 6/30/2020 6/30/2019 UNITS FY24 FY23 FY22 FY21 FY20 FY19 USAGE KWH 251,476,000 415,247,000 187,902,000 187,902,000 187,902,000 297,441,000 OPERATING BUDGET $3724200 2,544,100 1,992,890 2,007,385 2,168,391 2,024,298 MITCR KW 156,000 156,000 156,100 156,000 156,000 156,000 TOTAL 499.2 MW ENERGY (A)$.000/KWH $0.01237 $0.00512 $0.00886 $0.00892 $0.00964 $0.00568 NORTHERN UTILITY PARTICIPANTS (MW) CAPACITY (B)$/KW $3.94 $2.69 $2.11 $2.12 $2.29 $2.14 GVEA 191 204 204.7 205.5 204.7 MW TOTAL 204.7 MW MITCR DETERMINATION FY 24 KWH CAP RATE CAP CHARGES MEA 29.20% 22.80 MW 22,800 $3.94 89,832.00 CEA 70.80%55.20 MW 55,200 $3.94 217,488.00 GVEA 100.00%78.00 MW 78,000 $3.94 307,320.00 156.00 MW 156,000 614,640.00 (A) See Section 7.2.5 AK Intertie Agreement (B) See Section 7.2.6 AK Intertie Agreement MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS (MITCR) DETERMINATION FOR FISCAL YEAR 2024 Page 4 of 4 Alaska Energy Authority AK Intertie Budget to Actual Revenues and Expenses 07/01/2022 to 02/28/2023 Page 1 of 4 FY23 Approved Budget BUDGET 07/01/2022 - 02/28/2023 Actuals YTD Actuals as a % of Total Annual Budget OVER (UNDER) YTD Variance Revenue From Utilities AKI-GVEA 2,659,180 1,838,531 1,256,774 47%(581,758) AKI-CEA 405,435 320,324 320,324 79%- AKI-MEA 440,368 315,551 322,352 73%6,800 Total Revenue From Utilities 3,504,984 2,474,407 1,899,449 54%(574,958) Interest/Capital Credits - - 40,179 0%40,179 Total Revenues 3,504,984 2,474,407 1,939,628 55%(534,779) Total Revenues 3,504,984 2,474,407 1,939,628 55%(534,779) 56200 Station Expenses Golden Valley Electric AK Intertie-Substation Electricity Usage - - 2,677 0%2,677 Golden Valley Electric Total - - 2,677 0%2,677 56600 Misc Transmission Expense Alaska Energy Authority AK Intertie-Cell Phone Comm. Svc. for Wx Monitorin 13,000 8,667 6,981 54%(1,686) AK Intertie-Misc Studies as needed 546,000 364,000 - 0%(364,000) Alaska Energy Authority Total 559,000 372,667 6,981 1%(365,686) Golden Valley Electric AK Intertie-Private Line Telephone Service SCADA 10,000 6,667 3,010 30%(3,657) Golden Valley Electric Total 10,000 6,667 3,010 30%(3,657) 56601 Weather Monitoring Batteries Alaska Energy Authority AK Intertie-SLMS Support and Intertie Grnd Patrol 140,000 93,333 78,019 56%(15,315) Alaska Energy Authority Total 140,000 93,333 78,019 56%(15,315) 56700 Rents Alaska Energy Authority AK Intertie-Alaska Railroad 700 467 1,500 214%1,033 Alaska Energy Authority Total 700 467 1,500 214%1,033 Matanuska Electric Association AK Intertie-Talkeetna Storage 7,200 4,800 4,200 58%(600) AK Intertie-Equipment Rental - - 102 0%102 Matanuska Electric Association Total 7,200 4,800 4,302 60%(498) 57000 Maintenance of Station Equip Chugach Electric Association AK Intertie-Teeland Substation 173,200 115,467 51,718 30%(63,748) Chugach Electric Association Total 173,200 115,467 51,718 30%(63,748) Golden Valley Electric AK Intertie-Healy, Cantwell, Goldhill 75,000 50,000 111,019 148%61,019 AK Intertie-SCADA Maint Healy, Cantwell, Goldhill 5,000 3,333 - 0%(3,333) AK Intertie-Cantwell 4S2 Switch Repair 156,000 104,000 30,434 20%(73,566) AK Intertie-Maint & Repaint Reactors Healy SVC Yd 80,000 53,333 4,472 6%(48,861) Golden Valley Electric Total 316,000 210,667 145,925 46%(64,742) Matanuska Electric Association AK Intertie-Douglas Substation 25,000 16,667 - 0%(16,667) Matanuska Electric Association Total 25,000 16,667 - 0%(16,667) 57100 Maint of OH Lines Golden Valley Electric AK Intertie-Northern Maintenance 100,000 66,667 44,048 44%(22,618) Golden Valley Electric Total 100,000 66,667 44,048 44%(22,618) Matanuska Electric Association AK Intertie-Special Patrols (Incl Foundation Insp) 10,000 6,667 488 5%(6,179) ALASKA ENERGY AUTHORITY AK INTERTIE BUDGET TO ACTUAL REVENUE AND EXPENSES FOR THE PERIOD 07/01/2022 THROUGH 02/28/2023 Page 2 of 4 FY23 Approved Budget BUDGET 07/01/2022 - 02/28/2023 Actuals YTD Actuals as a % of Total Annual Budget OVER (UNDER) YTD Variance ALASKA ENERGY AUTHORITY AK INTERTIE BUDGET TO ACTUAL REVENUE AND EXPENSES FOR THE PERIOD 07/01/2022 THROUGH 02/28/2023 AK Intertie-Southern Maint. (Incl Ground Insp) 140,000 93,333 2,665 2%(90,668) AK Intertie-Equipment Repair and Replacement 684,000 456,000 - 0%(456,000) Matanuska Electric Association Total 834,000 556,000 3,153 0%(552,847) 57102 Maint OH Lines-ROW Clearing AK Intertie-Northern ROW Clearing 400,000 266,667 20,961 5%(245,706) Golden Valley Electric Total 400,000 266,667 20,961 5%(245,706) Matanuska Electric Association AK Intertie-Southern ROW Clearing 500,000 333,333 267,094 53%(66,239) Matanuska Electric Association Total 500,000 333,333 267,094 53%(66,239) 58306 Misc Admin AK Intertie-IMC Admin Cost (Audit, meeting, legal) 20,000 13,333 6,705 34%(6,628) Alaska Energy Authority Total 20,000 13,333 6,705 34%(6,628) 58401 Insurance Premiums Alaska Energy Authority AK Intertie-Insurance 25,000 16,667 22,183 89%5,516 Alaska Energy Authority Total 25,000 16,667 22,183 89%5,516 Total Total Expense 3,110,100 2,073,400 658,275 21%(1,415,125) Total Operating Expenses 3,110,100 2,073,400 658,275 21%(1,415,125) 71001 Total Expense, Budget Administrative Support Services 200,000 133,333 54,072 27%(79,261) Alaska Energy Authority Total 200,000 133,333 54,072 27%(79,261) Total Total Expense 200,000 133,333 54,072 27%(79,261) Total AEA Administration Expenses 200,000 133,333 54,072 27%(79,261) Total Expenses 3,310,100 2,206,733 712,347 22%(1,494,386) Surplus (Shortage)194,884 267,674 1,227,281 630%959,607 Page 3 of 4 Alaska Intertie FY23 Budget to Actuals Status Report for the Period 07/01/2022 through 02/28/2023 Budgeted Usage Actual Usage to Date GVEA MEA CEA TOTAL GVEA MEA CEA TOTAL MONTH MWH MWH MWH MWH MONTH MWH MWH MWH MWH Jul 32,301 1,918 - 34,219 Jul 10,865 2,252 - 13,117 Aug 36,741 1,968 - 38,709 Aug 19,648 2,239 - 21,887 Sep 37,596 1,951 - 39,547 Sep 21,418 2,080 - 23,498 Oct 40,739 2,003 - 42,742 Oct 35,865 2,205 - 38,070 Nov 35,783 2,269 - 38,052 Nov 16,159 2,213 - 18,372 Dec 35,761 2,455 - 38,216 Dec 16,826 2,535 - 19,361 Jan 35,543 2,139 - 37,682 Jan 13,942 2,363 - 16,305 Feb 30,397 2,018 - 32,415 Feb 36,444 2,162 - 38,606 Mar 33,294 2,171 - 35,465 Mar - - - - Apr 38,537 1,906 - 40,443 Apr - - - - May 33,177 1,867 - 35,044 May - - - - Jun 38,652 1,811 - 40,463 Jun - - - - TOTAL 428,521 24,476 - 452,997 TOTAL 171,167 18,049 - 189,216 INTERTIE PROJECTED ENERGY USAGE TO DATE (MWH)301,582 INTERTIE ACTUAL ENERGY USAGE TO DATE (MWH) 189,216 Budgeted Operating Costs for the Period 2,073,400$ Actual Operating Costs for the Period 658,275$ (based on amended budget) Budgeted Usage Revenue for the Period 1,544,100$ Actual (Billed) Usage Revenue for the Period 968,786$ (budgeted rate * projected usage)(budgeted rate * actual usage) Estimated Budgeted Energy Rate per MWH 5.74$ (based on budgeted costs and usage) Annual Budgeted Energy Rate (Billed Rate)5.12$ Projected Actual Energy Rate per MWH 2.90$ (based on minimum contract value)(based on actual costs and usage) Page 4 of 4 Intertie Management Committee Meeting IOC Report March 10, 2023 1.Intertie Operating Committee a.The IOC reviewed and is recommending approval of the attached vegetation management plan. Cost estimates to implement the plan are also attached for reference. Costs range from just over $1M to just under $500k depending on the year, with an average annual cost over the seven-year period of approximately $740k. b.The IOC also reviewed and is recommending that the IMC approve the attached remote sensing plan. Remote sensing uses lidar, orthophotography, and software to determine growth rates of vegetation, danger trees, structure and wire locations, and when used over multiple years develops a clearing plan that aligns with vegetation growth. The estimated cost for this service and a description of the service are attached. c.A draft 2024 budget was developed and is attached for the IMC’s review. 2.System Studies Subcommittee a.Bids to support a sychrophaser project were received last year and Electric Power Group (EPG) was found to be the lowest responsive bidder. A master services agreement (MSA) has been drafted with EPG and is attached for review along with a cost benefit analysis. Annual costs for EPG’s subscription service ranges from $250k to $300k under the MSA. This does not include utility labor that would be necessary to support the project. Utility labor and infrastructure needs for the project were discussed at the IOC. A motion to recommend approval of the project failed to pass at the IOC. However, the IOC did commit to do a thorough review of the cost benefit analysis and to look at the utility labor and infrastructure requirements for the project. Additional discussions regarding this project are anticipated at the next IOC meeting. b.The SSS is kicking off two additional studies. One will be to look at the impact inverter- based resources will have on the Railbelt system. Funding for this study in the 2023 budget so work is anticipated to begin on this before the next IOC meeting. A second study will look at the impact of upgrading the Northern Intertie to 230 kV. This system impact study is included in the draft 2024 budget. 3.SCADA & telecommunications Subcommittee a.The IOC had a brief discussion regarding out of step tripping on the Northern Intertie. Part of that discussion highlighted the need for communication infrastructure between Douglas and Healy. Based on that discussion, the IOC has requested an update on the scope, schedule, and cost to upgrade the existing communication between Anchorage and Douglas and to install communication between Douglas and Healy. Alaska Railbelt Transmission Intertie Utility Vegetation Management Plan North Segment: Theodore Substation to Healy Substation UVM Plan: Northern Intertie February 13, 2023 2 | P a g e Executive Summary The northern segment of the Alaska Railbelt Transmission Intertie is managed by the Alaska Intertie Management Committee (IMC). The segment begins at the Teeland Substation in Wasilla, AK and continues in a northerly direction to the Douglas Substation in Willow, AK. From Douglas Substation the intertie then continues along an Alaska Energy Authority (AEA) owned segment which ends at the Healy Substation in Healy, AK. These two, totaling approximately 195 miles, constitute the Northern Railbelt Intertie Segment. The utilities responsible for administering the Utility Vegetation Management (UVM) of these corridors are Matanuska Electric Association (MEA) and Golden Valley Electric Association (GVEA). The purpose of this Utility Vegetation Management Plan is to identify objectives and inform stakeholders for the purpose of managing potentially adverse vegetation impacts on the reliability of the Alaska Transmission Intertie. UVM Plan: Northern Intertie February 13, 2023 3 | P a g e Table of Contents Executive Summary ............................................................................................................ 2 1.Northern Intertie UVM: Locations and Utilities ................................................... 4 1.1 Theodore to Douglas - MEA................................................................................... 4 1.2 Douglas to Structure No. 382 - MEA ..................................................................... 4 1.3 Structure No. 382 to Healy – GVEA ...................................................................... 4 1.4 Utility Points of Contact – GVEA, MEA ..................................................................... 4 2.Mission Statement and Objectives .......................................................................... 5 2.1 Mission Statement ......................................................................................................... 5 2.2 Supporting Objectives ................................................................................................... 5 2.3 Mission & Objectives Summary ................................................................................... 5 3.UVM Factors & Controls ......................................................................................... 6 3.1 Site Vegetation Factors ................................................................................................. 6 3.2 Utility Tree Risk Assessment & Management.............................................................. 6 3.3 Controls & Methods ...................................................................................................... 7 4.Operational Guidelines ............................................................................................. 8 4.1 Planning ........................................................................................................................ 8 4.2 Monitoring .................................................................................................................... 8 4.3 Controlling .................................................................................................................... 8 4.4 Personnel & Contractors ............................................................................................... 9 5.Summary .................................................................................................................. 10 References ......................................................................................................................... 11 Appendix A ....................................................................................................................... 12 UVM Plan: Northern Intertie February 13, 2023 4 | P a g e 1.Northern Intertie UVM: Locations and Utilities The effected Northern Intertie segment consists of three (3) regions. This transmission corridor begins at Teeland Substation and ends at Healy Substation, totaling approximately 195 line-miles. The Utility Vegetation Management responsibilities of the Northern Intertie are assigned to both MEA and GVEA. 1.1 Theodore to Douglas - MEA The first of the three regions (also referred to as segments) begins near W. Compass Dive in Wasilla, AK, at Teeland Substation. Located opposite of Teeland Substation is Theodore Substation at 5060 Mainsail Ave. Wasilla, AK. This is the southernmost site (Theodore Substation) of this UVM Plan. This segment of approximately 25 line-miles is owned by MEA and ends at Douglas Substation off Willow Fishhook Rd. Willow, AK. MEA is responsible for the vegetation management of this segment. 1.2 Douglas to Structure No. 382 - MEA The second UVM region begins at Douglas Substation which is where the sequential AEA structure numbering begins in a northerly direction. This segment ends at the back-span of structure numbering 382 and is part of the 170 line-miles owned by AEA. MEA is responsible for the vegetation management of this segment. 1.3 Structure No. 382 to Healy – GVEA The northernmost UVM region begins at AEA structure numbering 382, five (5) miles north of the Susitna River. The segment is also owned by AEA, ending with structure number 766 at Healy Substation near Healy Spur Rd. Healy, AK. GVEA is responsible for the vegetation management of this segment. 1.4 Utility Points of Contact – GVEA, MEA The utility representatives for any IMC, AEA, public and/or governmental UVM inquiries are: GVEA – Director of Operations: o Name: Nathan Minnema o Phone: 907-458-5878 o Email: NJMinnema@gvea.com MEA – Senior Manager of Operations: o Name: Gary Meadows o Phone: 907-761-9310 o Email: Gary.Meadows@mea.coop UVM Plan: Northern Intertie February 13, 2023 5 | P a g e 2.Mission Statement and Objectives Following are the Mission Statement and objectives of the Utility Vegetation Management Plan. 2.1 Mission Statement The mission of this UVM Plan is to promote electrical transmission reliability of the Northern Intertie Segment by managing vegetation risk. 2.2 Supporting Objectives The following items are individual objectives which support and are part of the AK Intertie UVM Plan mission: Reliability and Economics: To support the delivery of safe, reliable, and economical electric service to utility rate payers. To optimize Utility Vegetation Management maintenance cost(s). To consider associated costs and the impact on all stakeholders. UVM Operations: To ensure that Utility Vegetation Maintenance operations are conducted in a safe, effective manner and in conformity with federal and state laws, regulations, and if applicable,permit conditions. To control incompatible plant species within assigned corridor widths. To enhance and propagate compatible plant species. To maintain site access and intended use. To provide operational flexibility which utilizes current Industry Best Management Practices while protecting environmentally sensitive locations (construction, restorations, tree risk abatement, etc.). To assess and manage tree risk adjacent to utility corridors, within the capacity of available resources and funding. Stakeholder Cooperation: To maintain points of contact from both MEA and GVEA, as representatives of their management area, for swift response to UVM inquiries. To ensure communications between effected stakeholders (may include GVEA, MEA, CEA, AEA, and IMC) regarding Intertie UVM and system health. 2.3 Mission & Objectives Summary The mission and objectives of this UVM Plan have been developed with the understanding that managing the large volume of vegetation associated with utility rights-of-way has significant challenges. This plan is purposed to establish and inform of the performance standards for planning, monitoring, and controlling vegetation. From these, each utility will then develop individual projects and/or Vegetation Maintenance Plans. UVM Plan: Northern Intertie February 13, 2023 6 | P a g e 3.UVM Factors & Controls The management of vegetation in any industry is influenced by many factors. The combination of UVM factors at each site directly influence the planning, monitoring, and controlling of vegetation. 3.1 Site Vegetation Factors 3.1.1 Zones The Northern Intertie is located in a Boreal Climatic Zone with Plant Hardiness Zones ranging from 1a to 4a. Vegetation Zones range from low elevation tundra and wetlands, through forested areas, and up to alpine tundra. 3.1.2 Topography Topography varies as the route is traversed and the corridor encounters conditions ranging from saturated lowlands to steep mountainous terrain. 3.1.3 Soils Site soils are diverse from location to location and can change multiple times within a single span. 3.1.4 Vegetation Species Vegetation species, particularly tall growing trees, are of generally low variety in the region. The genetic capacity of any plant species is the primary attribute considered with the other site factors when determining compatibility. 3.1.4.1 Common Tree Species Some of the native tree species most commonly impactful to UVM objectives, by common name, are Cottonwood, Birch, White Spruce, Black Spruce, Quaking Aspen, Alder, and Willow. 3.1.5 Vegetation Growth Rates Seasonal snowfall and sunlight availability create short yet vigorous growth periods. Select species exhibit extreme response growth to treatment and timing. 3.1.5 Biotic and Abiotic Disorders Likely the most notable biotic disorder in the region is the Spruce Bark Beetle. Additionally, abiotic disorders such as snow, wind, and ice loading are prime considerations. 3.1.6 Tree Risk The combination of the likelihood of an event and the severity of the potential consequences. In the context of trees, risk is the likelihood of a conflict or tree failure occurring and affecting a target and the associated consequences – personal injury, property damage, or disruption of activities (Goodfellow, 2020). 3.2 Utility Tree Risk Assessment & Management 3.2.1 Tree Risk Assessment A systematic process to identify, analyze, and evaluate tree risk (Goodfellow, 2020). 3.2.1.1 Limited Visual Assessment (Level 1) A visual assessment from a specified perspective such as foot, vehicle, or aerial (airborne) patrol of an individual tree or a population of trees near specified targets to identify specified conditions or obvious defects of concern (Goodfellow, 2020). UVM Plan: Northern Intertie February 13, 2023 7 | P a g e 3.2.1.2 Basic Assessment (Level 2) Detailed visual inspection of a tree surrounding site that may include the use of simple tools. It requires that a tree risk assessor walk completely around the tree trunk, looking at the site, aboveground roots, trunk, and branches (Goodfellow, 2020). 3.2.1.3 Advanced Assessment (Level 3) An assessment performed to provide detailed information about specific tree parts, defects, targets, or site conditions. Specialized equipment, data collection and analysis, and expertise are usually required (Goodfellow, 2020). 3.2.2 Tree Risk Management The application of policies, procedures, and practices to identify, evaluate, mitigate, monitor, and communicate tree risk (Goodfellow, 2020). 3.3 Controls & Methods 3.3.1 Biological Control Management of vegetation by establishment and conservation of compatible plant communities using competition, allelopathy, animals, insects, or pathogens (Miller, 2021). 3.3.2 Chemical Control Management of incompatible vegetation using herbicides or growth regulators (Miller, 2021). 3.3.3 Cultural Control Management of vegetation through the use of alternative land uses, including agricultural systems such as crops and pastures, parks, or other managed landscapes (Miller, 2021). 3.3.4 Physical Control Management of incompatible plants using manual and mechanical processes to remove, control, or alter target plants (Miller, 2021). 3.3.4.1 Manual Methods Management of vegetation using hand-operated tools such as handsaws and small power tools (Miller, 2021). 3.3.4.2 Mechanical Methods Management of vegetation using equipment, including those mounted with saws, masticators, mowers, or other devices (Miller, 2021). UVM Plan: Northern Intertie February 13, 2023 8 | P a g e 4.Operational Guidelines The task of Utility Vegetation Management requires that the remarkable variability when managing natural assets across vast distances be considered. The quantities of trees and vegetation which may impact a given system and the finite resources of any organization result in the need to prioritize asset and risk management. An example of how this may be calculated has been provided below to aid in the development and application of the Planning, Monitoring, and Controlling processes. Assessed Level of Risk or Compatibility = Site Vegetation Factors + Target and/or Intended Use Following the assessment of risk or compatibility, actions may then be taken according to tolerances, land ownership/permission, and available resources. The components of project scope, such as assigned widths, are then developed to achieve management objectives while maintaining fiscally responsibility. 4.1 Planning A line segment(s) shall be scheduled for maintenance such that vegetation does not violate action thresholds before treatment. Control of all incompatible vegetation, to the full assigned widths, shall be achieved at time of treatment to prevent the violation of action thresholds before the next scheduled treatment. MEA and GVEA have provided cyclical schedule (see Appendix A) for each transmission span in the Northern Intertie for initial planning. This may be adjusted based on monitoring results. MEA and GVEA will inform the Intertie utilities and/or contractor(s) which rights-of-way segments will be treated, the range of treatment dates and the possible controls and methods. 4.2 Monitoring The utilities and/or contractor(s) shall inspect rights-of-way for tree risks and incompatible vegetation density, clearance distances and stand composition on an annual basis. These inspections are necessary to detect changes in site conditions and/or the effectiveness of past treatments, which may affect maintenance priority. Anticipated projects which result from inspection findings shall be reported annually to the Alaska Intertie maintenance subcommittee to allow scheduling adjustments to be included in the following year’s budgeting process. 4.3 Controlling 4.3.1 Vegetation Compatibility Vegetation is classified as either compatible or incompatible based on the Site Vegetation Factors and the presence and location of electrical facilities. Incompatible vegetation is any plant form which is inconsistent with the rights-of-way use for electrical transmission. This includes, but is not limited to, safety of personnel and the public, interruption(s) in electrical service, maintenance of electrical facilities, and the ingress/egress to and from utility corridors. 4.3.2 Current Controls & Methods The UVM control currently practiced by the utilities is Physical Control. Both manual and mechanical methods are utilized to accomplish this control. 4.3.3 Selection of Methods The selection of methods is based on site conditions such as accessibility, vegetation factors, sensitivity, and seasonal conditions. Selection should consider economics, safety, environmental stewardship, and efficacy of treatment(s). UVM Plan: Northern Intertie February 13, 2023 9 | P a g e 4.3.3.1 Considerations: Manual Methods Manual methods may be used at any time of year and are used to protect environmentally sensitive areas, prevent damage to electrical facilities and/or personal property, and where site conditions prevent mechanical control methods. 4.3.3.2 Considerations: Mechanical Methods Mechanical methods are commonly used at sites where high incompatible stand volumes are encroaching action thresholds, limiting access to and/or traversal of corridors, and where herbicide use is prohibited. This method may be restricted by site conditions such as steep slopes, rocky terrain, obstructions, wet sites with deep, soft soils, debris on the right-of-way, and where seasonal site conditions preclude operation. 4.3.4 Site Access and Preservation ROW access will be through the use of established roadways whenever possible. If no permanent access route exists along a right-of-way, a pathway may be created during the treatment cycle and maintained as a suitable route. The contractor, MEA, or GVEA will have appropriate legal rights in advance to enter the right-of-way by other means. Unreasonable site damage or destruction during any phase of operation by the utilities or contractor, his agents or employees, must be repaired immediately to the satisfaction of MEA or GVEA, who will determine what constitutes unreasonable site damage. There may, at times, be exceptions to obtaining 100% control or removal at specific sites. Such exceptions may be vegetation which is a landscaping component at improved properties, riparian zones, or landowner refusals of UVM operations. All exceptions, however, must be maintained at acceptable distances that will not exceed action thresholds before the next anticipated treatment. Exceptions on such sites are designed to prevent any unreasonable adverse environmental and/or public relations effects. 4.3.5 Substations Treatments will also extend around the perimeter of substations, to achieve 100% controls, following all sensitive area restrictions. 4.4 Personnel & Contractors MEA and GVEA use utility staff as well as independent contractors for all vegetation management activities. The utilities require that staff and contractors comply with all applicable state and federal laws and regulations, and AK Intertie vegetation management specifications. Appropriate data, permits, and restriction lists must be provided to UVM staff prior to work on site. These organizations must provide: • Appropriately certified supervisors who understand all aspects of the contracted treatment and who are responsive to the guidance of MEA and / or GVEA; • Supervisors who effectively manage crews to ensure the satisfactory completion and reporting; • Supervisors who effectively communicate with the public; • Supervisors who ensure proper safety measures and PPE are being adhered to at all times in accordance with their companies Safety Manuals; • Experienced and/or trained workers, who are appropriately licensed or certified; • Workers who conduct themselves professionally at all times; • The appropriate equipment to maintain the highest practical level of efficiency and effectiveness; • Equipment in good visual and working condition; UVM Plan: Northern Intertie February 13, 2023 10 | P a g e 5.Summary This UVM Plan has provided vegetation planning, monitoring, and controlling purposed to promote electrical transmission reliability of the Northern Intertie. From this guidance each UVM manager will then develop the supporting projects utilizing best management practices and tacit knowledge of their assigned segments. Throughout the iterations of Northern Intertie UVM it will be a necessity to maintain communications with all stakeholders. Lastly, any UVM Plan will require revisions as management options and ecosystems evolve to remain effective. Therefore, revisions to this UVM Plan will be made, as necessary, to remain current and become more all-inclusive. UVM Plan: Northern Intertie February 13, 2023 11 | P a g e References Goodfellow, J. W. (2020). Utility Tree Risk Assessment. Atlanta, GA: International Society of Arboriculture. Miller, R. H. (2021). Integrated Vegetation Management Best Management Practices (3rd ed.). Atlanta: International Society of Arboriculture. UVM Plan: Northern Intertie February 13, 2023 12 | P a g e Appendix A Intertie Cycle Schedule Utility Structure #Vegetation Type Cycle Length (5 or 7 Years) GVEA 766 Spruce 5‐year Cycle GVEA 765 Spruce 5‐year Cycle GVEA 764 Spruce 7‐year Cycle GVEA 763 Spruce 7‐year Cycle GVEA 762 Spruce 7‐year Cycle GVEA 761 Spruce 7‐year Cycle GVEA 760 Spruce 7‐year Cycle GVEA 759 Spruce 7‐year Cycle GVEA 758 Spruce 7‐year Cycle GVEA 757 Spruce 7‐year Cycle GVEA 756 Spruce 7‐year Cycle GVEA 755 Spruce 7‐year Cycle GVEA 754 Spruce 7‐year Cycle GVEA 753 Spruce 7‐year Cycle GVEA 752 Spruce 7‐year Cycle GVEA 751 Spruce 7‐year Cycle GVEA 750 Spruce 7‐year Cycle GVEA 749 Spruce 7‐year Cycle GVEA 748 Spruce 7‐year Cycle GVEA 747 Spruce 7‐year Cycle GVEA 746 Spruce 7‐year Cycle GVEA 745 Spruce 7‐year Cycle GVEA 744 Spruce 7‐year Cycle GVEA 743 Spruce 7‐year Cycle GVEA 742 Spruce 7‐year Cycle GVEA 741 Spruce 7‐year Cycle GVEA 740 Spruce 7‐year Cycle GVEA 739 Spruce 7‐year Cycle GVEA 738 Spruce 7‐year Cycle GVEA 737 Spruce 7‐year Cycle GVEA 736 Spruce 7‐year Cycle GVEA 735 Spruce 7‐year Cycle GVEA 734 Spruce 7‐year Cycle GVEA 733 Spruce 7‐year Cycle GVEA 732 Spruce 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 13 | P a g e GVEA 731 Spruce 7‐year Cycle GVEA 730 Spruce 7‐year Cycle GVEA 729 Spruce 7‐year Cycle GVEA 728 Spruce 7‐year Cycle GVEA 727 Spruce 7‐year Cycle GVEA 726 Spruce 7‐year Cycle GVEA 725 Spruce 7‐year Cycle GVEA 724 Spruce 7‐year Cycle GVEA 723 Spruce 7‐year Cycle GVEA 722 Spruce 7‐year Cycle GVEA 721 Spruce 7‐year Cycle GVEA 720 Spruce 7‐year Cycle GVEA 719 Spruce 7‐year Cycle GVEA 718 Spruce 7‐year Cycle GVEA 717 Spruce 7‐year Cycle GVEA 716 Spruce 7‐year Cycle GVEA 715 Spruce 7‐year Cycle GVEA 714 Spruce 7‐year Cycle GVEA 713 Spruce 7‐year Cycle GVEA 712 Spruce 7‐year Cycle GVEA 711 Spruce 7‐year Cycle GVEA 710 Spruce 7‐year Cycle GVEA 709 Spruce 7‐year Cycle GVEA 708 Spruce 7‐year Cycle GVEA 707 Spruce 7‐year Cycle GVEA 706 Spruce 7‐year Cycle GVEA 705 Spruce 7‐year Cycle GVEA 704 Spruce 7‐year Cycle GVEA 703 Spruce 7‐year Cycle GVEA 702 Spruce 7‐year Cycle GVEA 701 Spruce 7‐year Cycle GVEA 700 Spruce 7‐year Cycle GVEA 699 Spruce 7‐year Cycle GVEA 698 Spruce 7‐year Cycle GVEA 697 Spruce 7‐year Cycle GVEA 696 Spruce 7‐year Cycle GVEA 695 Spruce 7‐year Cycle GVEA 694 Spruce 7‐year Cycle GVEA 693 Spruce 7‐year Cycle GVEA 692 Spruce 7‐year Cycle GVEA 691 Spruce 7‐year Cycle GVEA 690 Spruce 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 14 | P a g e GVEA 689 Spruce 7‐year Cycle GVEA 688 Spruce 7‐year Cycle GVEA 687 Spruce 7‐year Cycle GVEA 686 Spruce 7‐year Cycle GVEA 685 Spruce 7‐year Cycle GVEA 684 Hardwoods 5‐year Cycle GVEA 683 Hardwoods 5‐year Cycle GVEA 682 Hardwoods 5‐year Cycle GVEA 681 High Tundra No Clearing Needed GVEA 680 High Tundra No Clearing Needed GVEA 679 High Tundra No Clearing Needed GVEA 678 High Tundra No Clearing Needed GVEA 677 High Tundra No Clearing Needed GVEA 676 High Tundra No Clearing Needed GVEA 675 High Tundra No Clearing Needed GVEA 674 High Tundra No Clearing Needed GVEA 673 High Tundra No Clearing Needed GVEA 672 High Tundra No Clearing Needed GVEA 671 High Tundra No Clearing Needed GVEA 670 High Tundra No Clearing Needed GVEA 669 High Tundra No Clearing Needed GVEA 668 High Tundra No Clearing Needed GVEA 667 High Tundra No Clearing Needed GVEA 666 High Tundra No Clearing Needed GVEA 665 High Tundra No Clearing Needed GVEA 664 High Tundra No Clearing Needed GVEA 663 High Tundra No Clearing Needed GVEA 662 High Tundra No Clearing Needed GVEA 661 High Tundra No Clearing Needed GVEA 660 Spruce 7‐year Cycle GVEA 659 Spruce 7‐year Cycle GVEA 658 Spruce 7‐year Cycle GVEA 657 Spruce 7‐year Cycle GVEA 656 Spruce 7‐year Cycle GVEA 655 Spruce 7‐year Cycle GVEA 654 Spruce 7‐year Cycle GVEA 653 Spruce 7‐year Cycle GVEA 652 Spruce 7‐year Cycle GVEA 651 Spruce 7‐year Cycle GVEA 650 Spruce 7‐year Cycle GVEA 649 Spruce 7‐year Cycle GVEA 648 Spruce 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 15 | P a g e GVEA 647 Spruce 7‐year Cycle GVEA 646 Spruce 7‐year Cycle GVEA 645 Spruce 7‐year Cycle GVEA 644 Spruce 7‐year Cycle GVEA 643 Spruce 7‐year Cycle GVEA 642 Spruce 7‐year Cycle GVEA 641 Spruce 7‐year Cycle GVEA 640 Spruce 7‐year Cycle GVEA 639 Spruce 7‐year Cycle GVEA 638 Spruce 7‐year Cycle GVEA 637 Spruce 7‐year Cycle GVEA 636 Spruce 7‐year Cycle GVEA 635 Spruce 7‐year Cycle GVEA 634 Spruce 7‐year Cycle GVEA 633 Spruce 7‐year Cycle GVEA 632 Spruce 7‐year Cycle GVEA 631 Spruce 7‐year Cycle GVEA 630 Spruce 7‐year Cycle GVEA 629 Spruce 7‐year Cycle GVEA 628 Spruce 7‐year Cycle GVEA 627 Spruce 7‐year Cycle GVEA 626 Spruce 7‐year Cycle GVEA 625 Spruce 7‐year Cycle GVEA 624 Spruce 7‐year Cycle GVEA 623 Spruce 7‐year Cycle GVEA 622 Spruce 7‐year Cycle GVEA 621 Spruce 7‐year Cycle GVEA 620 Spruce 7‐year Cycle GVEA 619 Spruce 7‐year Cycle GVEA 618 Alder 7‐year Cycle GVEA 617 Alder 7‐year Cycle GVEA 616 Alder 7‐year Cycle GVEA 615 Alder 7‐year Cycle GVEA 614 Alder 7‐year Cycle GVEA 613 Alder 7‐year Cycle GVEA 612 Alder 7‐year Cycle GVEA 611 Alder 7‐year Cycle GVEA 610 Alder 7‐year Cycle GVEA 609 Alder 7‐year Cycle GVEA 608 Alder 7‐year Cycle GVEA 607 Alder 7‐year Cycle GVEA 606 Gravel Pit No Clearing Needed UVM Plan: Northern Intertie February 13, 2023 16 | P a g e GVEA 605 Gravel Pit No Clearing Needed GVEA 604 Hardwoods 7‐year Cycle GVEA 603 Hardwoods 7‐year Cycle GVEA 602 Hardwoods 7‐year Cycle GVEA 601 Hardwoods 7‐year Cycle GVEA 600 Hardwoods 7‐year Cycle GVEA 599 Hardwoods 5‐year Cycle GVEA 598 Hardwoods 7‐year Cycle GVEA 597 High Tundra No Clearing Needed GVEA 596 High Tundra No Clearing Needed GVEA 595 High Tundra No Clearing Needed GVEA 594 High Tundra No Clearing Needed GVEA 593 Hardwoods 7‐year Cycle GVEA 592 High Tundra No Clearing Needed GVEA 591 High Tundra No Clearing Needed GVEA 590 High Tundra No Clearing Needed GVEA 589 High Tundra No Clearing Needed GVEA 588 High Tundra No Clearing Needed GVEA 587 High Tundra No Clearing Needed GVEA 586 High Tundra No Clearing Needed GVEA 585 High Tundra No Clearing Needed GVEA 584 High Tundra No Clearing Needed GVEA 583 High Tundra No Clearing Needed GVEA 582 High Tundra No Clearing Needed GVEA 581 High Tundra No Clearing Needed GVEA 580 High Tundra No Clearing Needed GVEA 579 High Tundra No Clearing Needed GVEA 578 High Tundra No Clearing Needed GVEA 577 High Tundra No Clearing Needed GVEA 576 High Tundra No Clearing Needed GVEA 575 High Tundra No Clearing Needed GVEA 574 High Tundra No Clearing Needed GVEA 573 High Tundra No Clearing Needed GVEA 572 High Tundra No Clearing Needed GVEA 571 High Tundra No Clearing Needed GVEA 570 High Tundra No Clearing Needed GVEA 569 High Tundra No Clearing Needed GVEA 568 High Tundra No Clearing Needed GVEA 567 High Tundra No Clearing Needed GVEA 566 High Tundra No Clearing Needed GVEA 565 High Tundra No Clearing Needed GVEA 564 High Tundra No Clearing Needed UVM Plan: Northern Intertie February 13, 2023 17 | P a g e GVEA 563 High Tundra No Clearing Needed GVEA 562 High Tundra No Clearing Needed GVEA 561 High Tundra No Clearing Needed GVEA 560 High Tundra No Clearing Needed GVEA 559 High Tundra No Clearing Needed GVEA 558 High Tundra No Clearing Needed GVEA 557 High Tundra No Clearing Needed GVEA 556 High Tundra No Clearing Needed GVEA 555 High Tundra No Clearing Needed GVEA 554 Hardwoods 7‐year Cycle GVEA 553 Hardwoods 7‐year Cycle GVEA 552 Hardwoods 7‐year Cycle GVEA 551 High Tundra No Clearing Needed GVEA 550 High Tundra No Clearing Needed GVEA 549 High Tundra No Clearing Needed GVEA 548 High Tundra No Clearing Needed GVEA 547 Hardwoods 7‐year Cycle GVEA 546 High Tundra No Clearing Needed GVEA 545 High Tundra No Clearing Needed GVEA 544 High Tundra No Clearing Needed GVEA 543 High Tundra No Clearing Needed GVEA 542 High Tundra No Clearing Needed GVEA 541 High Tundra No Clearing Needed GVEA 540 High Tundra No Clearing Needed GVEA 539 High Tundra No Clearing Needed GVEA 538 High Tundra No Clearing Needed GVEA 537 High Tundra No Clearing Needed GVEA 536 High Tundra No Clearing Needed GVEA 535 High Tundra No Clearing Needed GVEA 534 High Tundra No Clearing Needed GVEA 533 High Tundra No Clearing Needed GVEA 532 High Tundra No Clearing Needed GVEA 531 High Tundra No Clearing Needed GVEA 530 High Tundra No Clearing Needed GVEA 529 High Tundra No Clearing Needed GVEA 528 High Tundra No Clearing Needed GVEA 527 High Tundra No Clearing Needed GVEA 526 High Tundra No Clearing Needed GVEA 525 High Tundra No Clearing Needed GVEA 524 Hardwoods 7‐year Cycle GVEA 523 Hardwoods 7‐year Cycle GVEA 522 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 18 | P a g e GVEA 521 Hardwoods 7‐year Cycle GVEA 520 Hardwoods 5‐year Cycle GVEA 519 Hardwoods 5‐year Cycle GVEA 518 Hardwoods 7‐year Cycle GVEA 517 Hardwoods 7‐year Cycle GVEA 516 High Tundra No Clearing Needed GVEA 515 High Tundra No Clearing Needed GVEA 514 High Tundra No Clearing Needed GVEA 513 High Tundra No Clearing Needed GVEA 512 High Tundra No Clearing Needed GVEA 511 High Tundra No Clearing Needed GVEA 510 High Tundra No Clearing Needed GVEA 509 High Tundra No Clearing Needed GVEA 508 High Tundra No Clearing Needed GVEA 507 High Tundra No Clearing Needed GVEA 506 High Tundra No Clearing Needed GVEA 505 High Tundra No Clearing Needed GVEA 504 High Tundra No Clearing Needed GVEA 503 High Tundra No Clearing Needed GVEA 502 High Tundra No Clearing Needed GVEA 501 High Tundra No Clearing Needed GVEA 500 High Tundra No Clearing Needed GVEA 499 High Tundra No Clearing Needed GVEA 498 High Tundra No Clearing Needed GVEA 497 High Tundra No Clearing Needed GVEA 496 High Tundra No Clearing Needed GVEA 495 High Tundra No Clearing Needed GVEA 494 High Tundra No Clearing Needed GVEA 493 Hardwoods 7‐year Cycle GVEA 492 High Tundra No Clearing Needed GVEA 491 High Tundra No Clearing Needed GVEA 490 High Tundra No Clearing Needed GVEA 489 High Tundra No Clearing Needed GVEA 488 High Tundra No Clearing Needed GVEA 487 High Tundra No Clearing Needed GVEA 486 High Tundra No Clearing Needed GVEA 485 Hardwoods 5‐year Cycle GVEA 484 Hardwoods 5‐year Cycle GVEA 483 Hardwoods 5‐year Cycle GVEA 482 Hardwoods 7‐year Cycle GVEA 481 Hardwoods 7‐year Cycle GVEA 480 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 19 | P a g e GVEA 479 Hardwoods 7‐year Cycle GVEA 478 Hardwoods 7‐year Cycle GVEA 477 Hardwoods 7‐year Cycle GVEA 476 Hardwoods 7‐year Cycle GVEA 475 Hardwoods 7‐year Cycle GVEA 474 High Tundra No Clearing Needed GVEA 473 High Tundra No Clearing Needed GVEA 472 High Tundra No Clearing Needed GVEA 471 High Tundra No Clearing Needed GVEA 470 High Tundra No Clearing Needed GVEA 469 Hardwoods 7‐year Cycle GVEA 468 Hardwoods 7‐year Cycle GVEA 467 Hardwoods 7‐year Cycle GVEA 466 Hardwoods 7‐year Cycle GVEA 465 Hardwoods 7‐year Cycle GVEA 464 Hardwoods 7‐year Cycle GVEA 463 Hardwoods 7‐year Cycle GVEA 462 Hardwoods 7‐year Cycle GVEA 461 High Tundra No Clearing Needed GVEA 460 High Tundra No Clearing Needed GVEA 459 High Tundra No Clearing Needed GVEA 458 High Tundra No Clearing Needed GVEA 457 High Tundra No Clearing Needed GVEA 456 High Tundra No Clearing Needed GVEA 455 Hardwoods 7‐year Cycle GVEA 454 High Tundra No Clearing Needed GVEA 453 High Tundra No Clearing Needed GVEA 452 High Tundra No Clearing Needed GVEA 451 High Tundra No Clearing Needed GVEA 450 High Tundra No Clearing Needed GVEA 449 High Tundra No Clearing Needed GVEA 448 Hardwoods 5‐year Cycle GVEA 447 Hardwoods 5‐year Cycle GVEA 446 Hardwoods 5‐year Cycle GVEA 445 Hardwoods 7‐year Cycle GVEA 444 Hardwoods 7‐year Cycle GVEA 443 Hardwoods 7‐year Cycle GVEA 442 High Tundra No Clearing Needed GVEA 441 High Tundra No Clearing Needed GVEA 440 Hardwoods 7‐year Cycle GVEA 439 High Tundra No Clearing Needed GVEA 438 High Tundra No Clearing Needed UVM Plan: Northern Intertie February 13, 2023 20 | P a g e GVEA 437 High Tundra No Clearing Needed GVEA 436 Hardwoods 7‐year Cycle GVEA 435 High Tundra No Clearing Needed GVEA 434 Hardwoods 7‐year Cycle GVEA 433 High Tundra No Clearing Needed GVEA 432 High Tundra No Clearing Needed GVEA 431 Low Brush Clear for access GVEA 430 High Tundra No Clearing Needed GVEA 429 High Tundra No Clearing Needed GVEA 428 High Tundra No Clearing Needed GVEA 427 High Tundra No Clearing Needed GVEA 426 High Tundra No Clearing Needed GVEA 425 High Tundra No Clearing Needed GVEA 424 High Tundra No Clearing Needed GVEA 423 High Tundra No Clearing Needed GVEA 422 High Tundra No Clearing Needed GVEA 421 High Tundra No Clearing Needed GVEA 420 High Tundra No Clearing Needed GVEA 419 High Tundra No Clearing Needed GVEA 418 High Tundra No Clearing Needed GVEA 417 High Tundra No Clearing Needed GVEA 416 High Tundra No Clearing Needed GVEA 415 High Tundra No Clearing Needed GVEA 414 High Tundra No Clearing Needed GVEA 413 High Tundra No Clearing Needed GVEA 412 High Tundra No Clearing Needed GVEA 411 High Tundra No Clearing Needed GVEA 410 High Tundra No Clearing Needed GVEA 409 High Tundra No Clearing Needed GVEA 408 High Tundra No Clearing Needed GVEA 407 High Tundra No Clearing Needed GVEA 406 High Tundra No Clearing Needed GVEA 405 High Tundra No Clearing Needed GVEA 404 High Tundra No Clearing Needed GVEA 403 High Tundra No Clearing Needed GVEA 402 High Tundra No Clearing Needed GVEA 401 High Tundra No Clearing Needed GVEA 400 High Tundra No Clearing Needed GVEA 399 High Tundra No Clearing Needed GVEA 398 High Tundra No Clearing Needed GVEA 397 High Tundra No Clearing Needed GVEA 396 High Tundra No Clearing Needed UVM Plan: Northern Intertie February 13, 2023 21 | P a g e GVEA 395 High Tundra No Clearing Needed GVEA 394 High Tundra No Clearing Needed GVEA 393 High Tundra No Clearing Needed GVEA 392 High Tundra No Clearing Needed GVEA 391 High Tundra No Clearing Needed GVEA 390 High Tundra No Clearing Needed GVEA 389 High Tundra No Clearing Needed GVEA 388 Hardwoods 7‐year Cycle GVEA 387 High Tundra No Clearing Needed GVEA 386 Hardwoods 7‐year Cycle GVEA 385 Hardwoods 7‐year Cycle GVEA 384 High Tundra No Clearing Needed GVEA 383 Hardwoods 7‐year Cycle GVEA 382 Hardwoods 7‐year Cycle MEA 381 Hardwoods 7‐year Cycle MEA 380 Hardwoods 7‐year Cycle MEA 379 Hardwoods 7‐year Cycle MEA 378 Hardwoods 7‐year Cycle MEA 377 Alders 7‐year Cycle MEA 376 Alders 7‐year Cycle MEA 375 Alders 7‐year Cycle MEA 374 High Tundra No Clearing Needed MEA 373 High Tundra No Clearing Needed MEA 372 High Tundra No Clearing Needed MEA 371 High Tundra No Clearing Needed MEA 370 High Tundra No Clearing Needed MEA 369 High Tundra No Clearing Needed MEA 368 High Tundra No Clearing Needed MEA 367 High Tundra No Clearing Needed MEA 366 High Tundra No Clearing Needed MEA 365 Alders 7‐year Cycle MEA 364 Alders 7‐year Cycle MEA 363 Alders 7‐year Cycle MEA 362 Hardwoods 7‐year Cycle MEA 361 Hardwoods 7‐year Cycle MEA 360 Hardwoods 7‐year Cycle MEA 359 Hardwoods 7‐year Cycle MEA 358 Hardwoods 7‐year Cycle MEA 357 Hardwoods 7‐year Cycle MEA 356 Hardwoods 7‐year Cycle MEA 355 Hardwoods 7‐year Cycle MEA 354 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 22 | P a g e MEA 353 Hardwoods 7‐year Cycle MEA 352 Hardwoods 7‐year Cycle MEA 351 Hardwoods 7‐year Cycle MEA 350 Hardwoods 7‐year Cycle MEA 349 Hardwoods 7‐year Cycle MEA 348 Hardwoods 7‐year Cycle MEA 347 Hardwoods 7‐year Cycle MEA 346 Hardwoods 7‐year Cycle MEA 345 Hardwoods 7‐year Cycle MEA 344 Hardwoods 7‐year Cycle MEA 343 Hardwoods 7‐year Cycle MEA 342 Hardwoods 7‐year Cycle MEA 341 Hardwoods 7‐year Cycle MEA 340 Hardwoods 7‐year Cycle MEA 339 Hardwoods 7‐year Cycle MEA 338 Hardwoods 7‐year Cycle MEA 337 Hardwoods 7‐year Cycle MEA 336 Hardwoods 7‐year Cycle MEA 335 Hardwoods 7‐year Cycle MEA 334 Hardwoods 7‐year Cycle MEA 333 Hardwoods 7‐year Cycle MEA 332 Hardwoods 7‐year Cycle MEA 331 Hardwoods 7‐year Cycle MEA 330 Hardwoods 7‐year Cycle MEA 329 Alders 7‐year Cycle MEA 328 Alders 7‐year Cycle MEA 327 High Tundra No Clearing Needed MEA 326 High Tundra No Clearing Needed MEA 325 High Tundra No Clearing Needed MEA 324 High Tundra No Clearing Needed MEA 323 High Tundra No Clearing Needed MEA 322 High Tundra No Clearing Needed MEA 321 High Tundra No Clearing Needed MEA 320 High Tundra No Clearing Needed MEA 319 High Tundra No Clearing Needed MEA 318 High Tundra No Clearing Needed MEA 317 High Tundra No Clearing Needed MEA 316 High Tundra No Clearing Needed MEA 315 High Tundra No Clearing Needed MEA 314 High Tundra No Clearing Needed MEA 313 High Tundra No Clearing Needed MEA 312 High Tundra No Clearing Needed UVM Plan: Northern Intertie February 13, 2023 23 | P a g e MEA 311 High Tundra No Clearing Needed MEA 310 High Tundra No Clearing Needed MEA 309 High Tundra No Clearing Needed MEA 308 High Tundra No Clearing Needed MEA 307 High Tundra No Clearing Needed MEA 306 High Tundra No Clearing Needed MEA 305 High Tundra No Clearing Needed MEA 304 High Tundra No Clearing Needed MEA 303 High Tundra No Clearing Needed MEA 302 High Tundra No Clearing Needed MEA 301 High Tundra No Clearing Needed MEA 300 High Tundra No Clearing Needed MEA 299 High Tundra No Clearing Needed MEA 298 High Tundra No Clearing Needed MEA 297 High Tundra No Clearing Needed MEA 296 High Tundra No Clearing Needed MEA 295 High Tundra No Clearing Needed MEA 294 High Tundra No Clearing Needed MEA 293 High Tundra No Clearing Needed MEA 292 High Tundra No Clearing Needed MEA 291 High Tundra No Clearing Needed MEA 290 High Tundra No Clearing Needed MEA 289 High Tundra No Clearing Needed MEA 288 High Tundra No Clearing Needed MEA 287 High Tundra No Clearing Needed MEA 286 High Tundra No Clearing Needed MEA 285 High Tundra No Clearing Needed MEA 284 High Tundra No Clearing Needed MEA 283 High Tundra No Clearing Needed MEA 282 High Tundra No Clearing Needed MEA 281 High Tundra No Clearing Needed MEA 280 High Tundra No Clearing Needed MEA 279 High Tundra No Clearing Needed MEA 278 High Tundra No Clearing Needed MEA 277 High Tundra No Clearing Needed MEA 276 High Tundra No Clearing Needed MEA 275 High Tundra No Clearing Needed MEA 274 High Tundra No Clearing Needed MEA 273 High Tundra No Clearing Needed MEA 272 High Tundra No Clearing Needed MEA 271 High Tundra No Clearing Needed MEA 270 High Tundra No Clearing Needed UVM Plan: Northern Intertie February 13, 2023 24 | P a g e MEA 269 High Tundra No Clearing Needed MEA 268 High Tundra No Clearing Needed MEA 267 High Tundra No Clearing Needed MEA 266 High Tundra No Clearing Needed MEA 265 High Tundra No Clearing Needed MEA 264 High Tundra No Clearing Needed MEA 263 High Tundra No Clearing Needed MEA 262 High Tundra No Clearing Needed MEA 261 High Tundra No Clearing Needed MEA 260 High Tundra No Clearing Needed MEA 259 High Tundra No Clearing Needed MEA 258 High Tundra No Clearing Needed MEA 257 High Tundra No Clearing Needed MEA 256 High Tundra No Clearing Needed MEA 255 High Tundra No Clearing Needed MEA 254 High Tundra No Clearing Needed MEA 253 High Tundra No Clearing Needed MEA 252 High Tundra No Clearing Needed MEA 251 Alders 7‐year Cycle MEA 250 Alders 7‐year Cycle MEA 249 Alders 7‐year Cycle MEA 248 Alders 7‐year Cycle MEA 247 Alders 7‐year Cycle MEA 246 Alders 7‐year Cycle MEA 245 Alders 7‐year Cycle MEA 244 Alders 7‐year Cycle MEA 243 Alders 7‐year Cycle MEA 242 Hardwoods 7‐year Cycle MEA 241 Hardwoods 7‐year Cycle MEA 240 Hardwoods 7‐year Cycle MEA 239 Hardwoods 7‐year Cycle MEA 238 Hardwoods 7‐year Cycle MEA 237 Hardwoods 7‐year Cycle MEA 236 Hardwoods 7‐year Cycle MEA 235 Hardwoods 7‐year Cycle MEA 234 Hardwoods 7‐year Cycle MEA 233 Hardwoods 7‐year Cycle MEA 232 Hardwoods 7‐year Cycle MEA 231 Hardwoods 7‐year Cycle MEA 230 Hardwoods 7‐year Cycle MEA 229 Hardwoods 7‐year Cycle MEA 228 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 25 | P a g e MEA 227 Hardwoods 7‐year Cycle MEA 226 Hardwoods 7‐year Cycle MEA 225 Hardwoods 7‐year Cycle MEA 224 Hardwoods 7‐year Cycle MEA 223 Hardwoods 7‐year Cycle MEA 222 Hardwoods 7‐year Cycle MEA 221 Hardwoods 7‐year Cycle MEA 220 Hardwoods 5‐year Cycle MEA 219 Hardwoods 5‐year Cycle MEA 218 Hardwoods 5‐year Cycle MEA 217 Hardwoods 5‐year Cycle MEA 216 Hardwoods 5‐year Cycle MEA 215 Hardwoods 5‐year Cycle MEA 214 Hardwoods 5‐year Cycle MEA 213 Hardwoods 5‐year Cycle MEA 212 Hardwoods 5‐year Cycle MEA 211 Hardwoods 5‐year Cycle MEA 210 Hardwoods 5‐year Cycle MEA 209 Hardwoods 5‐year Cycle MEA 208 Hardwoods 5‐year Cycle MEA 207 Hardwoods 5‐year Cycle MEA 206 Hardwoods 5‐year Cycle MEA 205 Hardwoods 5‐year Cycle MEA 204 Hardwoods 5‐year Cycle MEA 203 Hardwoods 5‐year Cycle MEA 202 Hardwoods 5‐year Cycle MEA 201 Hardwoods 5‐year Cycle MEA 200 Hardwoods 5‐year Cycle MEA 199 Hardwoods 5‐year Cycle MEA 198 Hardwoods 5‐year Cycle MEA 197 Hardwoods 5‐year Cycle MEA 196 Hardwoods 5‐year Cycle MEA 195 Hardwoods 5‐year Cycle MEA 194 Hardwoods 5‐year Cycle MEA 193 Hardwoods 5‐year Cycle MEA 192 Hardwoods 5‐year Cycle MEA 191 Hardwoods 5‐year Cycle MEA 190 Hardwoods 5‐year Cycle MEA 189 Hardwoods 5‐year Cycle MEA 188 Hardwoods 5‐year Cycle MEA 187 Hardwoods 5‐year Cycle MEA 186 Hardwoods 5‐year Cycle UVM Plan: Northern Intertie February 13, 2023 26 | P a g e MEA 185 Hardwoods 5‐year Cycle MEA 184 Hardwoods 5‐year Cycle MEA 183 Hardwoods 5‐year Cycle MEA 182 Hardwoods 5‐year Cycle MEA 181 Hardwoods 5‐year Cycle MEA 180 Hardwoods 5‐year Cycle MEA 179 Hardwoods 5‐year Cycle MEA 178 Hardwoods 5‐year Cycle MEA 177 Hardwoods 5‐year Cycle MEA 176 Hardwoods 5‐year Cycle MEA 175 Hardwoods 5‐year Cycle MEA 174 Hardwoods 5‐year Cycle MEA 173 Hardwoods 5‐year Cycle MEA 172 Hardwoods 5‐year Cycle MEA 171 Hardwoods 5‐year Cycle MEA 170 Hardwoods 5‐year Cycle MEA 169 Hardwoods 5‐year Cycle MEA 168 Hardwoods 5‐year Cycle MEA 167 Hardwoods 5‐year Cycle MEA 166 Hardwoods 5‐year Cycle MEA 165 Hardwoods 5‐year Cycle MEA 164 Hardwoods 5‐year Cycle MEA 163 Hardwoods 5‐year Cycle MEA 162 Hardwoods 5‐year Cycle MEA 161 Hardwoods 5‐year Cycle MEA 160 Hardwoods 5‐year Cycle MEA 159 Hardwoods 5‐year Cycle MEA 158 Hardwoods 5‐year Cycle MEA 157 Hardwoods 5‐year Cycle MEA 156 Hardwoods 5‐year Cycle MEA 155 Hardwoods 7‐year Cycle MEA 154 Hardwoods 7‐year Cycle MEA 153 Hardwoods 7‐year Cycle MEA 152 Hardwoods 7‐year Cycle MEA 151 Hardwoods 7‐year Cycle MEA 150 Hardwoods 7‐year Cycle MEA 149 Hardwoods 7‐year Cycle MEA 148 Hardwoods 7‐year Cycle MEA 147 Hardwoods 7‐year Cycle MEA 146 Hardwoods 7‐year Cycle MEA 145 Hardwoods 7‐year Cycle MEA 144 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 27 | P a g e MEA 143 Hardwoods 7‐year Cycle MEA 142 Hardwoods 7‐year Cycle MEA 141 Hardwoods 7‐year Cycle MEA 140 Hardwoods 7‐year Cycle MEA 139 Hardwoods 7‐year Cycle MEA 138 Hardwoods 7‐year Cycle MEA 137 Hardwoods 7‐year Cycle MEA 136 Hardwoods 7‐year Cycle MEA 135 Hardwoods 7‐year Cycle MEA 134 Hardwoods 7‐year Cycle MEA 133 Hardwoods 7‐year Cycle MEA 132 Hardwoods 7‐year Cycle MEA 131 Hardwoods 7‐year Cycle MEA 130 Hardwoods 7‐year Cycle MEA 129 Hardwoods 7‐year Cycle MEA 128 Hardwoods 7‐year Cycle MEA 127 Hardwoods 7‐year Cycle MEA 126 Hardwoods 7‐year Cycle MEA 125 Hardwoods 7‐year Cycle MEA 124 Hardwoods 7‐year Cycle MEA 123 Hardwoods 7‐year Cycle MEA 122 Hardwoods 7‐year Cycle MEA 121 Hardwoods 7‐year Cycle MEA 120 Hardwoods 7‐year Cycle MEA 119 Hardwoods 7‐year Cycle MEA 118 Hardwoods 7‐year Cycle MEA 117 Hardwoods 7‐year Cycle MEA 116 Hardwoods 7‐year Cycle MEA 115 Hardwoods 7‐year Cycle MEA 114 Hardwoods 7‐year Cycle MEA 113 Hardwoods 7‐year Cycle MEA 112 Hardwoods 7‐year Cycle MEA 111 Hardwoods 7‐year Cycle MEA 110 Hardwoods 7‐year Cycle MEA 109 Hardwoods 7‐year Cycle MEA 108 Hardwoods 7‐year Cycle MEA 107 Hardwoods 7‐year Cycle MEA 106 Hardwoods 7‐year Cycle MEA 105 Hardwoods 7‐year Cycle MEA 104 Hardwoods 7‐year Cycle MEA 103 Hardwoods 7‐year Cycle MEA 102 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 28 | P a g e MEA 101 Hardwoods 7‐year Cycle MEA 100 Swamp No Clearing MEA 99 Swamp No Clearing MEA 98 Hardwoods 7‐year Cycle MEA 97 Hardwoods 7‐year Cycle MEA 96 Hardwoods 7‐year Cycle MEA 95 Hardwoods 7‐year Cycle MEA 94 Hardwoods 7‐year Cycle MEA 93 Hardwoods 7‐year Cycle MEA 92 Hardwoods 7‐year Cycle MEA 91 Hardwoods 7‐year Cycle MEA 90 Hardwoods 7‐year Cycle MEA 89 Hardwoods 7‐year Cycle MEA 88 Hardwoods 7‐year Cycle MEA 87 Hardwoods 7‐year Cycle MEA 86 Hardwoods 7‐year Cycle MEA 85 Hardwoods 7‐year Cycle MEA 84 Hardwoods 7‐year Cycle MEA 83 Swamp No Clearing MEA 82 Swamp No Clearing MEA 81 Swamp No Clearing MEA 80 Swamp No Clearing MEA 79 Swamp No Clearing MEA 78 Swamp No Clearing MEA 77 Swamp No Clearing MEA 76 Swamp No Clearing MEA 75 Swamp No Clearing MEA 74 Swamp No Clearing MEA 73 Hardwoods 7‐year Cycle MEA 72 Hardwoods 7‐year Cycle MEA 71 Hardwoods 7‐year Cycle MEA 70 Hardwoods 7‐year Cycle MEA 69 Hardwoods 7‐year Cycle MEA 68 Hardwoods 7‐year Cycle MEA 67 Hardwoods 7‐year Cycle MEA 66 Hardwoods 7‐year Cycle MEA 65 Hardwoods 7‐year Cycle MEA 64 Hardwoods 7‐year Cycle MEA 63 Hardwoods 7‐year Cycle MEA 62 Hardwoods 7‐year Cycle MEA 61 Hardwoods 7‐year Cycle MEA 60 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 29 | P a g e MEA 59 Hardwoods 7‐year Cycle MEA 58 Hardwoods 7‐year Cycle MEA 57 Hardwoods 7‐year Cycle MEA 56 Hardwoods 7‐year Cycle MEA 55 Hardwoods 7‐year Cycle MEA 54 Hardwoods 7‐year Cycle MEA 53 Hardwoods 7‐year Cycle MEA 52 Hardwoods 7‐year Cycle MEA 51 Hardwoods 7‐year Cycle MEA 50 Hardwoods 7‐year Cycle MEA 49 Hardwoods 7‐year Cycle MEA 48 Swamp No Clearing MEA 47 Swamp No Clearing MEA 46 Swamp No Clearing MEA 45 Swamp No Clearing MEA 44 Swamp No Clearing MEA 43 Hardwoods 7‐year Cycle MEA 42 Hardwoods 7‐year Cycle MEA 41 Hardwoods 7‐year Cycle MEA 40 Hardwoods 7‐year Cycle MEA 39 Hardwoods 7‐year Cycle MEA 38 Hardwoods 7‐year Cycle MEA 37 Hardwoods 7‐year Cycle MEA 36 Swamp No Clearing MEA 35 Swamp No Clearing MEA 34 Hardwoods 7‐year Cycle MEA 33 Hardwoods 7‐year Cycle MEA 32 Hardwoods 7‐year Cycle MEA 31 Hardwoods 7‐year Cycle MEA 30 Hardwoods 7‐year Cycle MEA 29 Hardwoods 7‐year Cycle MEA 28 Hardwoods 7‐year Cycle MEA 27 Hardwoods 7‐year Cycle MEA 26 Hardwoods 7‐year Cycle MEA 25 Hardwoods 7‐year Cycle MEA 24 Hardwoods 7‐year Cycle MEA 23 Hardwoods 7‐year Cycle MEA 22 Hardwoods 7‐year Cycle MEA 21 Hardwoods 7‐year Cycle MEA 20 Hardwoods 7‐year Cycle MEA 19 Hardwoods 7‐year Cycle MEA 18 Hardwoods 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 30 | P a g e MEA 17 Hardwoods 7‐year Cycle MEA 16 Hardwoods 7‐year Cycle MEA 15 Hardwoods 7‐year Cycle MEA 14 Hardwoods 7‐year Cycle MEA 13 Hardwoods 7‐year Cycle MEA 12 Swamp No Clearing MEA 11 Swamp No Clearing MEA 10 Swamp No Clearing MEA 9 Swamp No Clearing MEA 8 Hardwoods 7‐year Cycle MEA 7 Hardwoods 7‐year Cycle MEA 6 Hardwoods 7‐year Cycle MEA 5 Hardwoods 7‐year Cycle MEA 4 Hardwoods 7‐year Cycle MEA 3 Hardwoods 7‐year Cycle MEA 2 Hardwoods 7‐year Cycle MEA 1 Hardwoods 7‐year Cycle MEA H2DG-115 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-114 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-113 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-112 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-111 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-110 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-109 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-108 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-107 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-106 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-105 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-104 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-103 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-102 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-101 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-100 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-99 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-98 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-97 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-96 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-95 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-94 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-93 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-92 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 31 | P a g e MEA H2DG-91 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-90 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-89 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-88 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-87 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-86 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-85 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-84 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-83 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-82 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-81 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-80 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-79 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-78 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-77 Mix of willow/alder, wetlands, and boreal forest 7‐year Cycle MEA H2DG-76 Swamp 7‐year Cycle MEA H2DG-75 Swamp 7‐year Cycle MEA H2DG-74 Swamp 7‐year Cycle MEA H2DG-73 Boreal Forest 7‐year Cycle MEA H2DG-72 Boreal Forest 7‐year Cycle MEA H2DG-71 Boreal Forest 7‐year Cycle MEA H2DG-70 Boreal Forest 7‐year Cycle MEA H2DG-69 Boreal Forest 7‐year Cycle MEA H2DG-68 Boreal Forest 7‐year Cycle MEA H2DG-67 Alder/willow 7‐year Cycle MEA H2DG-66 Alder/willow 7‐year Cycle MEA H2DG-65 Alder/willow 7‐year Cycle MEA H2DG-64 Alder/willow 7‐year Cycle MEA H2DG-63 Wetlands No Clearing Needed MEA H2DG-62 Wetlands No Clearing Needed MEA H2DG-61 Wetlands No Clearing Needed MEA H2DG-60 Heavily burnt Boreal Forest 7‐year Cycle MEA H2DG-59 Heavily burnt Boreal Forest 7‐year Cycle MEA H2DG-58 Heavily burnt Boreal Forest 7‐year Cycle MEA H2DG-57 Heavily burnt Boreal Forest 7‐year Cycle MEA H2DG-56 Heavily burnt Boreal Forest 7‐year Cycle MEA H2DG-55 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-54 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-53 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-52 Mixed boreal forest and swamps/wetlands 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 32 | P a g e MEA H2DG-51 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-50 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-49 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-48 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-47 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-46 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-45 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-44 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-43 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-42 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-41 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-40 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-39 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-38 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-37 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-36 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-35 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-34 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-33 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-32 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-31 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-30 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-29 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-28 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA H2DG-27 Mixed boreal forest and swamps/wetlands 7‐year Cycle MEA TLH2-1-0 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-1 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-2 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-3 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-4 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-5 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-6 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-7 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-8 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-9 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-10 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-11 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-12 Mix of swamps and burnt boreal forest 7‐year Cycle MEA TLH2-13 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-14 Primarily Mature Boreal Forest 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 33 | P a g e MEA TLH2-15 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-16 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-17 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-18 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-19 Primarily Mature Boreal Forest 7‐year Cycle MEA TDL2-20 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-21 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-22 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-23 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-24 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-25 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-26 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-27 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-28 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-29 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-30 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-31 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-32 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-33 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-34 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-35 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-36 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-37 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-38 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-39 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-40 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-41 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-42 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-43 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-44 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-45 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-46 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-46 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-47 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-48 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-49 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-50 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-51 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-52 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-53 Primarily Mature Boreal Forest 7‐year Cycle UVM Plan: Northern Intertie February 13, 2023 34 | P a g e MEA TLH2-55 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-55 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-56 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-56A Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-57 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-58 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-59 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-60 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-61 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-62 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-63 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-64 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-65 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-66 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-67 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-68 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-69 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-70 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-71 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-72 Primarily Mature Boreal Forest 7‐year Cycle MEA TLH2-73 Primarily Mature Boreal Forest 7‐year Cycle MEA TEDU-74 Primarily Mature Boreal Forest 7‐year Cycle MEA TEDU-75 Primarily Mature Boreal Forest 7‐year Cycle MEA TEDU-76 Primarily Mature Boreal Forest 7‐year Cycle Northern Intertie Seven Year Clearing Costs 2024 2025 2026 2027 2028 2029 2030 GVEA Annual Clearing Cost 604,800.00$ 630,750.00$ 446,688.00$ 388,422.00$ 371,163.00$ 375,721.00$ 380,507.00$ MEA Annual Clearing Cost 500,000.00$ -$ -$ 270,760.41$ 425,552.95$ 345,783.33$ 417,204.58$ Total Clearing Costs 1,104,800.00$ 630,750.00$ 446,688.00$ 659,182.41$ 796,715.95$ 721,504.33$ 797,711.58$ Northern Intertie Seven Year Remote Sensing Costs 2024 2025 2026 2027 2028 2029 2030 GVEA Remote Sensing Cost 125,000.00$ 250,000.00$ 262,500.00$ 275,625.00$ 289,406.25$ 303,876.56$ 319,070.39$ MEA Reomte Sensing Cost 500,000.00$ 525,000.00$ 551,250.00$ 578,812.50$ 607,753.13$ 638,140.78$ 670,047.82$ Total Remote Sensing Cost 625,000.00$ 775,000.00$ 813,750.00$ 854,437.50$ 897,159.38$ 942,017.34$ 989,118.21$ *Detailed cost estimates from each utility are on the following two pages Rev Date 2-27-23 GVEA Clearing Costs 2024 2025 2026 2027 2028 2029 2030 Section 1 Miles (Pole 660 to Pole 577)17.3 Section 2 Miles (Pole 525 to Pole 446)18 Section 3 Miles (Pole 446 to Pole 382)14 Section 4 Miles (Pole 577 to Pole 525)11.6 Section 5 Miles (Pole 682 to Pole 710)5.6 Section 6 Miles(Pole 710 to Pole 738)5.6 Section 7 Miles (Pole 738 to Pole 766)5.6 Section 660-682, 6.8 Miles No Work Needed 6.8 Total Miles/Year 24.1 18 14 11.6 5.6 5.6 5.6 Section 1 Cost/Mile (Pole 660 to Pole 557)26,000$ Section 2 Cost/Mile (Pole 525 to Pole 446)26,000$ Section 3 Cost/Mile (Pole 446 to Pole 382)26,000$ Section 4 Cost/Mile (Pole 577 to Pole 525)26,000$ Section 5 Cost/Mile (Pole 682 to Pole 710)50,000$ Section 6 Cost/Mile (Pole 710 to Pole 738)50,000$ Section 7 Cost/Mile (Pole 738 to Pole 766)50,000$ Total Clearing Cost/Year 449,800$ 468,000$ 364,000$ 301,600$ 280,000$ 280,000$ 280,000$ Access Reclaim 80,000.00$ 84,000.00$ -$ -$ -$ -$ -$ Annual Helipatrol for Hotspots and LZ clearing 75,000$ 78,750$ 82,688$ 86,822$ 91,163$ 95,721$ 100,507$ Total 604,800$ 630,750$ 446,688$ 388,422$ 371,163$ 375,721$ 380,507$ $500k Remote Sensing + 5% adder Annually 500,000$ 525,000$ 551,250$ 578,813$ 607,753$ 638,141$ 670,048$ 5.5 AEA Str#195-220 8.9 AEA Str#156-195 12.5 AEA Str#240-382 3.9 AEA Str#221-239 15.8 AEA Str#001-069 10.1 AEA Str#070-115 9.1 AEA Str#116-155 8.6 T2D Str#077-115 10.1 T2D Str#076-027 5.0 TLH2-1-0 to TEDU76 12.5 14.1 24.7 20.2 18.0 Cycle Cost 5yr Cycle Cost 7yr Cycle Total Cost Access Reclaim Remote Sensing Total MEA Northern Intertie Seven Year UVM Work & Budget Projections *All are estimated and subject to changes such as schedule adjustments due to site conditions, fuel/oil/gas, etc.* *All values have a 5% annual increase applied. All costs/mile are based on historical pricing for each of the regional project groups.* *All are estimated and subject to change such as schedule adjustments due to site conditions, fuel/oil/gas, vendor pricing, etc.* *The 89.5 miles above reflects only locations which currently indicate the need for treatment(s). There are approximately 18 line-miles which indicate no treatment(s) needed. Bringing the total line-miles represented to 107.5 miles.* Cost/Mile 7yr cycle South of Talkeetna River Cost/Mile 7 Douglas to Teeland $546,385.41 Miles 5yr cycle North of Talkeetna River & Structure I.D.'s Miles 5yr cycle South of Talkeetna River & Structure I.D.'s Miles 7yr cycle North of Talkeetna River & Structure I.D.'s Miles 7yr cycle South of Talkeetna River & Structure I.D.'s Miles 7yr Douglas to Teeland & Structure I.D.'s $13,894.76 $150,709.71 $120,050.70 $270,760.41 $0.00 $275,625.00 2027 $27,401.77 $425,552.95 $0.00 $289,406.25 $714,959.20 $21,186.27 $14,999.69 $188,557.84 $236,995.11 203020292028 $417,204.58 $16,125.23 $23,357.87 $31,800.47 $736,274.97 $319,070.39 $0.00 $417,204.58$345,783.32 $0.00 $303,876.56 $649,659.89 $18,939.43 $15,357.36 $345,783.32 $0.00 $0.00 $250,000.00 $250,000.00 $262,500.00 2025 $0.00 $0.00 $262,500.00 2026 $355,950.00 $355,950.00 $144,050.00 $125,000.00 $28,476.00 Total Miles Cost/Mile 5yr cycle North of Talkeetna River Cost/Mile 5yr cycle South of Talkeetna River Cost/Mile 7yr cycle North of Talkeetna River $625,000.00 2024 Remote Sensing and Analysis of AEA owned Intertie Transmission Assets and Vegetation Project Schedule: Data Collection in July 2023. Data Processing period of 4-6 weeks. Delivery of Analysis and management application(s) in mid-September 2023. Scope: Location: AEA owned assets and corridor from Douglas substation to Healy substation. Deliverables: Post-processed remote sensing data which geolocates and identifies AEA assets and vegetation with cloud-based management tools Benefits: Asset and Vegetation Mapping with one meter or less accuracies. High resolution asset images. Vegetation data. Vegetation fall-in, grow-in, and health analysis. Threat Analysis of vegetation. Multi-user mobile and web application for use in field or office. Cloud-based solution which does not require analysis or on-site storage by the customer. Increased Budgeting Accuracies and Capabilities. Trend Analysis. Risk Reporting. Capability of greater asset and vegetation monitoring through follow-up collections. Cost: $413,725.00 Not Included: This does not include thermal or electrical discharge imaging. These costs will be provided as available. * It was noted by the proposer that the Corona type cameras may be best deployed as a handheld unit to allow for more cost-effective monitoring. * i Adam C. McCullough Alaska Program Manager +907.632.4364 | adam.mccullough@nv5.com ALASKA ENERGY AUTHORITY: LIDAR SURVEY AND ANALYSIS OF WILLOW TO HEALY TRANSMISSION LINE Prepared For Alaska Energy Authority akenergyauthority.org Date Submitted February 10, 2023 AEA Lidar Survey & Analysis | 1 T able of Contents Project Overview 3 Area of Interest __________________________ 3 Deliverables _____________________________ 3 Schedule _______________________________ 4 Project Status updates _____________________ 5 INSITE Project Tracker _______________________ 5 Data Collection 5 Safety __________________________________ 5 Methodology ____________________________ 5 Rotary-Wing Collection with Class System _______ 5 Geodetic Survey 6 Methodology ____________________________ 6 Static Control ______________________________ 7 Ground Survey Points _______________________ 7 Vegetation Field Survey ____________________ 7 Vegetation Management Analysis 8 VM Analysis Methodology __________________ 8 Lidar Calibration & Classificaiton ______________ 8 Pole & Span Locations _____________________ 8 Fall-in & Grow-in Analysis ____________________ 9 Multi-spectral imagery Analysis ____________ 10 Vegetation Polygons _______________________ 10 Vegetation Species & Health Analysis _________ 10 Asset Images ___________________________ 12 Orthoimagery __________________________ 12 Delivery 13 Cloud Viewing Platform (buy-up Option) _____ 13 INSITE Core ______________________________ 13 INSITE Tessalator __________________________ 14 Project Costs 15 AEA Lidar Survey & Analysis | 2 T able of Tables & Figures Table 1. Geodetic survey specification ........................................................................................................................7 Table 2. Lidar feature codes ........................................................................................................................................8 Table 3. Project costs ............................................................................................................................................... 15 Figure 1. Lines represent project areas of interest .....................................................................................................3 Figure 3. Helicopter with NV5 Geospatial’s CLASS payload ........................................................................................4 Figure 2 . Tree species derived from ray tracing analysis ............................................................................................4 Figure 4. INSITE’s Project Tracker metrics & map .......................................................................................................5 Figure 5. CLASS sensor package ..................................................................................................................................5 Figure 6. Riegl VUX-240 lidar sensor ...........................................................................................................................6 Figure 7. PhaseOne ortho- cameras ............................................................................................................................6 Figure 8. PhaseOne oblique camera ...........................................................................................................................6 Figure 9. FS collection of an aerial target ....................................................................................................................6 Figure 10. Corrected pole locations in the new lidar dataset .....................................................................................8 Figure 11. Vegetation encroachment modeling..........................................................................................................9 Figure 12. Vegetation encroachments in the lidar point cloud ...................................................................................9 Figure 13. Tree crown polygons derived from ray tracing analysis .......................................................................... 10 Figure 14. Tree crown polygons attributed with species from ray tracing analysis ................................................. 10 Figure 15. Ray tracing analysis ................................................................................................................................. 11 Figure 16. Vegetation health analysis year over year 6 ........................................................................................... 11 Figure 17. Pole top image ........................................................................................................................................ 12 Figure 24. Ray tracing analysis ................................................................................................................................. 15 Figure 21. Vegetation encroachments in the point cloud ............................................. Error! Bookmark not defined. Figure 22. Cessna Conquest - Twin Engine Turbine ................................................................................................. 16 AEA Lidar Survey & Analysis | 3 PROJECT OVERVIEW This project aims to capture high-resolution remote sensing data and deliver derived products on schedule, on budget, and to the required specifications. Our proposal reflects tailored workflows developed to support the requested deliverable and schedule requirements. The flight plan, aerial profile, lidar scanning system, and sensor settings are adjusted to meet the appropriate conductor’s point spacing requirement, cover tension sections in a single flight line, and with a camera shutter cycle to capture both continuous ROW obliques and high-resolution structure imagery. Our dedicated calibration team will review all flights before demobilization to ensure quality & coverage of wire and right of way. The data specifications for this project entail 30+ points per square meter (ppsm) lidar, 3-inch 4-band orthoimagery, and oblique imagery collected within the 300-foot corridor centered on the transmission line. At a later date, NV5 Geospatial will provide a proposal for thermal imaging to identify and analyze electrical fault/discharge locations on AEA assets. AREA OF INTEREST The Willow to Healy transmission line is approximately 169 miles. This proposal is proving a cost option for a stand- alone collection & processing of AEA’s Willow to Healy transmisson line and an cost option for collecting the data in collaboration with MEA’s area of interest (AOI). DELIVERABLES AEA Assets Analyzed data set with the coordinates, asset type, and designator (pole tag) of each AEA Primary Overhead and Transmission Facility with accuracies of 1 meter or less. Esri standard File Geo Database (FGDB) format in Coordinate System: NAD 1983 StatePlane Alaska 4 FIPS 5004 (Feet). Figure 1. Lines represent project areas of interest AEA Willow-Healy MEA AOI AEA Lidar Survey & Analysis | 4 Vegetation Species Analyzed data set defining the species and health of vegetation. Esri standard FGDB format in Coordinate System: NAD 1983 StatePlane Alaska 4 FIPS 5004 (Feet). Vegetation Impact Capacity Analyzed data set defining the proximity of vegetation to AEA facilities/electrical conductors and the associated threat (grow-in/fall-in) posed with accuracies of 1 meter or less. Esri standard FGDB format in Coordinate System: NAD 1983 StatePlane Alaska 4 FIPS 5004 (Feet). Asset Images Oblique imagery of each AEA transmission facility located within the project. Images must be of a quality high enough to differentiate assemblies and reasonably gain a general impression of their condition. Images geolocated to the corresponding Transmission Facility. Both compressed (JPEG, PNG) and uncompressed (TIF, SID) image files. Data Report Upon project completion, NV5 Geospatial will provide a project data report. This pdf document will outline collection, processing, and analytic methods, as well as identify requested accuracies of the final datasets in addition to a survey control report signed by an Alaska PLS. SCHEDULE Data acquisition is slated to take place in July when trees will be at their peak for species identification analysis. Data processing is expected to take 4-6 weeks and will be delivered upon completion. A project schedule will be finalized at the kick-off meeting. Figure 3 . Tree species derived from ray tracing analysis Figure 2. Helicopter with NV5 Geospatial’s CLASS payload AEA Lidar Survey & Analysis | 5 PROJECT STATUS UPDATES INSITE PROJECT TRACKER INSITE’s Project Tracker module breaks down communication and planning barriers for large-scale geospatial data collection. INSITE presents your flight plan or ground survey progress in an elegant web map, providing visibility and transparency for all project stakeholders. No more waiting for next Monday’s status report: INSITE’s simple upload system allows data collection teams to refresh flight line status and report daily results within minutes of landing. Continuously updated heat maps and statistics enable you and your vendor to intelligently re-task resources when challenges arise. Data processing stats help you track project health through the final delivery. Centralized, single-source data keeps all funding partners and project stakeholders on the same page. DATA COLLECTION SAFETY NV5 Geospatial maintains strict safety standards throughout all operations. We maintain the ISNetworld Grade A rating for Tier 1 level activity. Our airborne remote sensing operators conduct a full Safety Brief prior to every mission day. A copy of the Safety Brief is automatically emailed to our Acquisition Director and key management personnel. METHODOLOGY ROTARY-WING COLLECTION WITH CLASS SYSTEM Our CLASS 2.0 sensor provides high-accuracy, high-resolution lidar and imagery data for a variety of remote sensing needs from a single rotary acquisition pass. The sensor package utilizes state-of-the- art commercially available components, including two Riegl VUX-240 lidar sensors, three PhaseOne iXM RS150F digital cameras, an Applanix POS AV 610 inertial navigation system, and an AIMMS weather probe. The sensor combo is designed to mount on a rotary aircraft for low-altitude, low-speed capture of corridor facilities. The resulting data provides best-in-class accuracy and resolution where it matters most. Figure 4. INSITE’s Project Tracker metrics & map Figure 5. CLASS sensor package AEA Lidar Survey & Analysis | 6 CLASS LIDAR The CLASS 2.0 system is outfitted with two Riegl Vux-240 lidar sensors to capture, each at different angles, to provide fore-aft look angles, resulting in a cross-hatch scan pattern. This configuration allows the illumination of targets, such as utility towers, buildings, or vegetation at high pulse densities and multiple look angles in a single pass. The lidar sensors have a full angle field-of- view of 330 degrees, which allows for creative project design in urban settings, steep canyons, and other applications that benefit from extreme off-nadir views. CLASS ORTHOIMAGERY NV5 Geospatial’s CLASS solution employs a Phase One iXM-RS100F 100 mm lens. The system simultaneously collects panchromatic and multispectral (RGB, NIR) imagery. The resulting orthoimagery will meet or exceed project accuracy specifications. This camera system is advanced in size and performance, allowing NV5 Geospatial to complete mapping projects with greater efficiency. NV5 Geospatial’s cameras significantly reduce the risk of re-flights from camera failure, common in older models. CLASS OBLIQUES Oblique images are collected at a distance that ensures complete coverage using a forward-facing PhaseOne150MP camera. Information from onboard GPS and IMU devices is recorded during the duration of the flight mission as image frames are captured. In the office, production team members refine these GPS and IMU measurements and link them to each captured image frame. To learn more about our CLASS systems and for detailed specifications, please review our online brochure at https://fliphtml5.com/yutcn/upls GEODETIC SURVEY METHODOLOGY NV5 Geospatial is familiar with utility industry best practices for collecting and reporting on the accuracy of imagery data compared to independently collected field verification data. NV5 Geospatial owns and operates multiple sets of Trimble Global Navigation Satellite System (GNSS) dual-frequency L1-L2 receivers, which are used in both static and roving surveys. The final project data report will contain our control network and control check points. Figure 6. Riegl VUX-240 lidar sensor Figure 7. PhaseOne ortho- cameras Figure 8. PhaseOne oblique camera Figure 9. FS collection of an aerial target AEA Lidar Survey & Analysis | 7 STATIC CONTROL Our team collects static positional data across the project area to support airborne missions. We have developed a set of criteria that enable us to improve our overall data quality (ground-based and airborne) and rely on our experienced field team with manager and Professional Land Surveyor (PLS) oversight to make safe, smart decisions regarding an efficient ground control network. Depending on logistics, including configuration of sites, access, schedule, and weather, NV5 Geospatial will use one or more appropriate methods for geospatial correction of aircraft data. These include conventional base-supported (BS) survey control, Precise Point Positioning (PPP), Post-Processed Real-Time Extended (PP-RTX). These processes include using the Continuous Operation Reference System (CORS) and/or project monuments. GROUND SURVEY POINTS Ground Control Points (GCPs) are collected on bare earth locations such as paved, gravel or stable dirt roads, and other locations where the ground is visible (and likely to remain visible) from the sky during data acquisition. In order to facilitate comparisons with lidar datasets, measurements are not taken on highly reflective surfaces, such as railroad crossing or stop bar markings on roads; alternatively, these features are preferable for imagery GCPs and are captured for this purpose. NV5 Geospatial will utilize Real-Time Network (RTN) when cell phone coverage is available and precisions allow, to access real-time corrections from CORS; NV5 Geospatial has numerous accounts with both public and private providers. A Real-Time Kinematic (RTK) survey allows for precise measurements near established monuments via radio broadcast for a real-time correction to a roving unit. For areas where base radio does not reach, Post- Processed Kinematic (PPK) is used. Fast Static (FS) is a post-processing technique when baselines are too far for PPK and is commonly used for remote aerial targets. VEGETATION FIELD SURVEY To classify the canopied area of interest into the species and health classifications, it is necessary to collect field data to create reference data for the species and health modeling exercise. The field campaign will be designed to capture the full range of variation in species and health statuses throughout the area of interest. It is expected that 30-45 field plots will be needed to characterize this area of interest. Locations to visit will be discussed with AEA based on their local experience and knowledge of land ownership and accessibility. The field plots should be accurately geolocated and capture detailed information about the dominant trees within each plot, such as total height, species, and tree health. Plot centers should be recorded with a high-quality GPS, actual location should be within 3 meters of mapped location. For each plot, 3-5 dominant trees need to be stem- mapped, i.e. individual trees are recorded with an identifier and their distance and azimuth from plot center is measured. This allows the trees to be identified in the point cloud. Adjustment of plot geolocation to match the point cloud is usually required and will be carried out by NV5 Geospatial. Geodetic Survey Measurements survey specification Static Control • 1Hz and GPS+GLONASS capable • Techniques: CORS, NGS Benchmarks, Custom GCPs • RMSExy <1.5cm and RMSEz <2.0cm • Techniques: RTN, RTK, PPK, FS Table 1. Geodetic survey specification AEA Lidar Survey & Analysis | 8 For this project, NV5 Geospatial will perform a species field survey. Additional cost savings can be realized if AEA has this internal capability. VEGETATION MANAGEMENT ANALYSIS VM ANALYSIS METHODOLOGY LIDAR CALIBRATION & CLASSIFICAITON The overall goal of lidar point processing is to rapidly create highly accurate data. Kinematic GPS solutions are resolved by combining aircraft positions with static ground positions. A smoothed best estimate of trajectory (SBET) is developed to blend aircraft positions with attitude data. Laser point positions are calculated, creating a raw laser point cloud, where each point retains the corresponding scan angle, return number (echo), intensity, and x, y, z information. Points are imported into corridors to filter noise and perform manual relative accuracy calibration. Ground points are then classified for individual flight lines to be used for relative accuracy testing and calibration. Automated line-to-line calibrations are performed to adjust for system attitude (pitch, roll, heading), mirror flex (scale), and GPS/IMU drift. Calibrations are performed on ground-classified points from paired flight lines; every flight line is used for relative accuracy calibration. Fundamental vertical accuracy is assessed via direct comparisons of ground-classified lidar points to ground point survey data. NV5 Geospatial employs automated, in-house methods for lidar feature delineation. Accurate feature coding of the point cloud is essential for supporting vegetation management projects. NV5 Geospatial's automated point cloud classification allows for the swift assembly of finalized 3D design files of circuit geospatial information. NV5 Geospatial classifies the lidar data utilizing the SCE Vegetation Management feature code classification scheme. POLE & SPAN LOCATIONS An accurate pole inventory is necessary for performing an effective assessment of all its attachments. Utilizing classified lidar, NV5 Geospatial can identify and update pole locations, provided as the distribution pole inventory. Each pole is attributed and assigned a unique ID. NV5 Geospatial will make every Lidar Point Cloud Feature Codes id description 1 Default (points below 12') 2 Ground (Bare Earth) 5 Vegetation above 1' 6 Non-Vegetation Features (i.e., Buildings) 7 Noise 14 Electric Structures 15 Conductors Figure 10. Corrected pole locations in the new lidar dataset Table 2. Lidar feature codes AEA Lidar Survey & Analysis | 9 effort to conflate and attribute poles with the utility’s naming criteria. Method-1 structure models made in PLS-CADD are a stick figure representation of the utility pole. There is no graphical display of the structure beyond vertical and horizontal lines that define the basic insulator and wire attachment geometry. The attributes to be assessed in this inventory are cable orientation, communication attachment points, down guys, etc. 3D CAD files covering the project area contain the following attachments on each pole: primary power spans, secondary power spans, communication spans, pole-to-pole guy spans, neutral power spans, and attached equipment. These results can be compiled and hosted on NV5 Geospatial's INSITE hosting service and delivered as a PLS-CADD Back Up file (.bak) for use in desktop CAD software. Method-1 structures are then strung from section to section utilizing client-approved PLS-CADD wire (*.wir) files that reference information including voltage, wire type, and stranding. The PLS-CADD batch thermal calculation process allows NV5 Geospatial to input wire and weather info for use in generating span-specific cable surface and core temperatures using the IEEE Standard 738-2006 calculation method. Wires were then graphically sagged using PLS-CADD finite element sag tension to meet fit points found using feature-coded lidar survey points. This yields an as-flown wire model that accurately represents the positions of the transmission wires at the time of survey. This model can be adjusted to represent maximum operating temperature and wind event conditions. FALL-IN & GROW-IN ANALYSIS NV5 Geospatial has created a system for identifying varying levels of severity for vegetation grow-in and fall-in threats. Vegetation clearance points are identified in the lidar point cloud to model conductors at maximum-sway and -sag conditions. The client provides PLS-CADD insulator libraries, cable files, criteria files, and wire ratings for the vegetation threat analysis. NV5 Geospatial identifies threats associated with individual tree crown points and attribute them with the most severe of each detected point cloud cluster. Threat clearance distances are calculated within PLS-CADD on each point within the feature-coded point cloud. Detection information is associated with vegetation crown polygons, which depict the extent of individual tree crowns based on point cloud geometry. Vegetation threats can be represented as points, such as the highest point or the closest danger point to the conductor within a cluster. The analysis is run using the following conductor operating conditions with vegetation threats Figure 11. Vegetation encroachment modeling Figure 12. Vegetation encroachments in the lidar point cloud AEA Lidar Survey & Analysis | 10 gathered from lidar processing: Max-Sag and Blowout (6# 60°F Bare). Threat detections are associated with vegetation polygons and entered into the project delivery geodatabase. MULTI-SPECTRAL IMAGERY ANALYSIS VEGETATION POLYGONS As a part of the tree species and health classification, vegetation polygons representing tree and shrub canopy clumps will be created through analysis of the lidar point cloud. For dispersed trees, the vegetation polygons will correspond to an individual tree crown, however, within dense forests, they will generally capture the dominant and co-dominant tree crowns with some segments representing multiple trees. The analysis will primarily rely upon height-above-ground information, as well as the distribution of proximate lidar returns. Each identified vegetation polygon will be attributed with height (in feet), species group, and health classification. VEGETATION SPECIES & HEALTH ANALYSIS In general, it is difficult to match a specific pixel to a specific tree when matching imagery to a lidar point cloud. This is because traditionally, the imagery is rectified to the ground and the tree displacement increases as the height of the tree increases and the angle widens between the specific pixel and the nadir point on the image. To address this, some companies rectify the image to the tree top surface. Although this can work, it tends to create a smeared image because of the rapid change in elevation on the side of trees. NV5 Geospatial has Figure 13. Tree crown polygons derived from ray tracing analysis Figure 14. Tree crown polygons attributed with species from ray tracing analysis AEA Lidar Survey & Analysis | 11 developed an innovative proprietary routine that can colorize a specific point within the lidar point cloud based on its precise corresponding image pixel. We do this by “tracing” each lidar ray back to the camera image plane to identify the specific corresponding pixel’s spectral values. Using the spectral and structural information made possible by the ray tracing method, NV5 Geospatial has developed an approach that utilizes the stem-mapped field data to train machine learning classifiers to classify the species and health of vegetation polygons. Vegetation indices, imagery texture metrics, and structural metrics derived from the lidar point cloud are summarized to each vegetation polygon and reference trees from the field data are matched with the polygons to create the classifier training dataset. If the classification schemes allow, skilled photo interpreters will augment the training dataset for the species and health models by creating additional species and health labels for vegetation polygons across the project area. Classifiers are trained based on the geometric, structural, and spectral characteristics of reference trees and used to predict tree species and health throughout the area of interest. It is expected that no more than five species groups will be targeted for this analysis and each species group will be well represented in the field data. Custom species and health classification schemes will be defined in collaboration with AEA to meet project goals and fully represent the area of analysis. Figure 15. Ray tracing analysis Figure 16. Vegetation health analysis year over year 6 AEA Lidar Survey & Analysis | 12 ASSET IMAGES NV5 Geospatial creates continuous overlapping circuit- specific imagery for asset inventory, cataloging, and re- engineering design. Each image set is produced to derive time information at the client-specified location, such as towers and continuous row images, using 150MP cameras. Raw image frames are reviewed for sharpness, exposure, and tonal quality and are converted to a common format (TIFF/JPEG/ECW) for further processing. Using proprietary software, images are georeferenced and reviewed for alignment with known feature locations. Once this alignment has been confirmed, target images are extracted to yield a visual of the full right-of-way width, with the desired frame-to-frame overlap between subsequent images. These images are reviewed by the production team for quality and completeness during the finalization process. The exact position of each oblique image is georeferenced during acquisition with geo-tagging hardware. The final imagery will undergo quality assurance for location, naming, color, and sharpness quality. Oblique imagery will be continuous, overlapping, in full color, and captured at a minimum every 100 feet along the transmission line. ORTHOIMAGERY For all survey work, NV5 Geospatial can supply 4-band georeferenced orthophotos encompassing the entire right- of-way width, continuously along each centerline within the ROW. Image radiometric values are calibrated to specific gain and exposure settings associated with each capture. The calibrated images are saved in *.tif format for input to subsequent processes. Photo position and orientation are calculated by linking the time of image capture, the corresponding aircraft position and attitude, and the SBET data. Within the sensor-specific software suite, automated aerial triangulation is performed to tie images together and adjust block to align with ground control. Adjusted images are then draped upon the lidar-derived ground model and orthorectified. Individual orthorectified *.tiffs are blended together to remove seams and corrected for any remaining radiometric differences between images using sensor-specific software. Final imagery is saved as the client-specified file type for input into the intended viewing software. Figure 17. Pole top image AEA Lidar Survey & Analysis | 13 DELIVERY CLOUD VIEWING PLATFORM (BUY-UP OPTION) INSITE CORE Deliverables, along with project tracking, will be made available through our cloud-hosted platform, INSITE. It is acknowledged that acceptance of the data will be in accordance with mutually agreed upon acceptance criteria in addition to 100% functionality within INSITE. Rolling data deliveries will be provided as the production of early data collection surveys is completed and while the remaining collection surveys are completed. Once data uploads are complete, the NV5G Project Manager will provide notifciation, via email, about which corridors are available. Data delivery will be reported during the weekly updates. The platform is scalable and agnostic, designed to provide a single source of truth for the entire organization. The INSITE platform will allow geospatial data to be shared across business units and teams. The extensible design makes it simple to add modules or functionality as geospatial needs evolve. Customer filters can be based on criteria to support dashboard analysis along with span-level actions for a vegetation management program and species of concern. INSITE provides on-demand access to cloud-hosted GIS and map data, 3D models, and analytics dashboards. Web-based architecture makes INSITE a true cross-platform solution, compatible with any major operating system or internet-connected device. INSITE HIGHLIGHTS Using the various remote sensing data, the solution will process and create optimized work plans to ensure the most proactive and efficient use of our resources. Specifically, for vegetation, the solution can allow customization between routine work and special program rules, work processes, and tasks. These data will be integrated into a utility’s existing systems for operationalization. Using the various lidar and analyses, AEA will be able to create optimized work plans to ensure the most proactive and efficient use of resources, identifying trees of concern and meet the clearance criteria with the ability to report out at the circuit, span, and plot-level the total number of trees, volume of trim (if purchased), predictive risk score to filter and contextualize tree removals, finally leveraging all analytics to build the work plan of the trim program. Specifically, for vegetation, the solution will allow for transmission assessment, work plan, and reporting of trim to be completed. These data will be exported/integrated into existing WMS systems for operationalization. Figure 18. INSITE schematic AEA Lidar Survey & Analysis | 14 ACTIONABLE DASHBOARD & REPORTING INSITE comes with a Dashboard view that allows users to define a program based on a set of criteria or filters for a given dataset. Once the program is defined, the INSITE dashboard will present all the data necessary for full context of dashboard results (cycle, year, line, unit-based vs preventative mile comparisons) and will display the progress of each program in an easy-to-digest format. As the user creates work orders in INSITE and then integrates these curated work bundles with their work planning management systems, the dashboard keeps track of the progress of every asset or tree until each line reaches 100% in the system. INSITE’s dashboard ensures you have a complete view of your data from start to finish in the cycle and that no work goes unaddressed. The magnitude of remote sensing can be daunting, but with INSITE’s dashboard, you can ensure you take action on everything that fits your program’s criteria. INSITE TESSALATOR NV5G offers its very own tessellator service, which is used to create image basemap caches from orthoimagery and host and serve them as a service for geospatial applications. We have developed a custom software product to rapidly ingest and tile orthorectified imagery in GeoTIFF and other formats, as well as Web Map Tile Service (WMTS) systems to display the data in a wide range of party software products. The Tessellator system is a proven toolset that has been utilized to process and display thousands of square miles of aerial orthorectified imagery to customers in our INSITE family of products. It is optimized for rapid image processing in a high compute environment and designed to handle the extremely large image datasets utilities typically work with. All orthorectified imagery data can be ingested into the Tessellator system where appropriate tiling, and organization of the data, will be performed. Once processed, data will be available via the WMTS interface, and ready for download. Figure 19. INSITE dashboard Figure 20. INSITE Tessalator AEA Lidar Survey & Analysis | 15 PROJECT COSTS Pricing is provided for AEA’s AOI with an option to collect concurrently with MEA’s AOI. Costs are provided for collection and processing tasks in the table below. ITEM DETAILS WLW-HLS WITH MEA COLLECT Data Collection • Lidar/Ortho/Oblique Acquisition • NV5 Acquisition Coordination • Ground Survey • Office Land Survey $139,331 $184,044 Lidar Processing • Calibration Bridge / Calibration • Ground Model Editing • Alignments / Alignments QC • Advanced Lidar Processing 1-10 Classes / QC $37,322 $51,021 Imagery Processing • Calibration Bridge / Calibration • Bridge Team • Ortho Processing / Ortho Processing QC • Oblique Imagery Processing / QC $35,808 $47,142 Vegetation Analysis • RGBNIR Ray-Traced Imagery • 4-band Imagery Vegetation Species ID $64,524 $83,808 PLS-CADD Modeling • Insulators (new .baks) • Tower Reports (new .baks) • Method 1s (new .baks) • String & Sag + Line Loading (new.baks) $19,972 $26,549 Vegetation Detection & Attribution • Veg Detections • Geodatabase $13,627 $18,179 Project & Processing Mgmt, Data Report & Archiving • Production Management • Project Management • Data Report • Archiving $78,452 $102,667 INSITE Project Tracker • Track project data collection & delivery status $4,688 $6,171 TOTAL $393,725 $519,582 INSITE Core & Tesselator (Buy-up) • Lidar, Imagery, & Analysis results hosted on the cloud $19,999 $20,002 Table 3. Project costs AEA Lidar Survey & Analysis | 16 Thank you POINT OF CONTACT Adam C. McCullough Alaska Program Manager +907.632.4364 adam.mccullough@nv5.com OFFICE LOCATION 2014 Merrill Field Dr Anchorage, AK 99501 +907.272.4495 nv5.com/geospatial Figure 19. Cessna Conquest - Twin Engine Turbine - Used for wide-area Lidar and Imagery acquisition from 2,000’ to 20,000’ AGL Alaska Intertie FY24 Approved Budget FY23 Approved Proposed FY15 FY16 FY17 FY18 FY19 FY20 FY21 FY22 ACTUALS FY23 FY24 Actual Actual Actual Actual Actual Actual Actual Actual @12/31/22 Budget Budget REVENUES GVEA 2,056,392 2,971,977 1,326,928 1,819,599 1,856,523 1,554,543 1,942,988 2,075,721 956,242 2,659,181 3,587,188 ML&P 217,355 196,819 105,652 285,075 146,246 237,938 111,217 CEA 235,695 209,205 115,519 298,554 166,406 258,090 290,065 265,259 277,769 405,435 453,395 MEA 271,940 335,586 162,479 350,920 247,774 448,478 460,479 413,239 256,628 440,368 634,655 INTEREST 266 2,842 4,801 6,636 32,412 16,611 903 1,668 18,440 TOTAL REVENUES 2,781,648 3,716,429 1,715,379 2,760,783 2,449,361 2,515,661 2,805,652 2,755,887 1,509,078 3,504,985 4,675,238 EXPENSES FERC 562 - Station Operation Expenses GVEA - Substation Electricity Usage 8,076 5,174 7,946 7,624 7,199 9,675 9,382 45,889 2,677 --Per GVEA 8,076 5,174 7,946 7,624 7,199 9,675 9,382 45,889 2,677 -- FERC 566 - Miscellaneous Transmission Expense Private Line Telephone Service for AKI SCADA (GVEA)55,641 49,163 49,701 47,810 32,793 11,718 5,556 5,556 3,010 10,000 -Per GVEA Cell Phone Comm. Svc for Weather Monitoring (Verizon)14,140 29,642 24,926 11,736 12,022 12,022 11,904 12,025 4,980 13,000 13,000 Per AEA SLMS Support and Intertie Ground Patrol 46,180 47,652 105,217 59,073 79,290 87,863 98,540 154,947 25,601 140,000 175,000 Per AEA Misc Studies as needed (Cyber Security Study)15,377 ---------- 131,338 126,457 179,844 118,618 124,105 111,603 116,000 172,528 33,591 163,000 188,000 FERC 567 - Transmission Expenses - Rents Rents - Alaska Railroad 700 700 700 700 700 700 700 700 1,500 700 -Fixed MEA - Talkeetna Storage 7,200 7,200 7,200 7,200 7,200 7,200 7,200 7,200 3,600 7,200 -Fixed Equipment Return -------375 102 - PSSE key replacement -------- 7,900 7,900 7,900 7,900 7,900 7,900 7,900 8,275 5,202 7,900 - FERC 569 Maintenance of Structures MEA - Maintenance of Structures -9,580 ---------Per MEA MEA - Re-insulate 20 dead-end structures 420,000 MEA - Re-insulate 30 tangent structures 320,000 ----------- -9,580 -----740,000 FERC 570 - Maintenance of Station Equipment GVEA - Healy, Cantwell, Goldhill 91,657 27,641 91,490 46,976 14,892 104,224 154,917 63,163 111,019 75,000 125,000 Per GVEA GVEA - SCADA Maintenance Healy, Cantwell, Gold Hill -4,007 -6,265 1,790 ----5,000 -Per GVEA GVEA - Replace Healy Substation Breaker B17 -----------Per GVEA GVEA - Healy, Teeland, Goldhill Dampers -4,007 ---59,016 -----Per GVEA GVEA - Healy and Goldhill Digital Fault Recorders 53,255 --Per IOC GVEA - Healy SVC Fire Alarm Panel Replacement (56,289)---1,697 ------Per GVEA GVEA - Gold Hill SVC Fire Alarm Panel Replacement (151,776)---------Per GVEA GVEA - Gold Hill SVC Cooling 460 --Per GVEA GVEA - Cantwell Install Breakers or Load Break Switches 5,029 -----182,606 30,434 156,000 156,000 Per GVEA GVEA - Cantwell 4S2 Switch Repair ---3,778 ------Per GVEA GVEA - Replace Battery Healy SVC --23,532 -------Per GVEA GVEA - Replace Battery Goldhill SVC --14,325 3,272 ------Per GVEA GVEA - Perform Maintenance, repaint Reactors Healy SVC Yard ---6,785 19,820 60,414 145,494 ----Per GVEA GVEA - Perform Maintenance, repaint Reactors Gold Hill SVC Yard 7,452 4,472 80,000 -Per GVEA GVEA - Mobile Substation Site ----------Per GVEA GVEA - Cantwell RTU, Recloser, & Transformer Protection replacement ----------Per GVEA GVEA - Recloser Control Replacement ----------Per GVEA GVEA - Transformer Protection Upgrades ----------Per GVEA GVEA - Dissolved Gas Monitoring Gold Hill & Healy ----------Per GVEA GVEA - Cantwell Standby Generator Replacement 29,016 -Per GVEA GVEA - SVC Intertie Trust Fund Eligible Expenses ------Per GVEA SVC ALASKA INTERTIE TRUST FUND ------Per IMC CEA - AK Intertie Yard ---------- CEA - Teeland Substation Communication --5,000 5,000 Per CEA CEA - Teeland Substation 51,540 167,628 70,713 70,882 82,890 113,849 183,401 115,365 50,548 168,200 170,000 Per CEA MEA - Douglas Substation 138 kV BKR Inspections 25,000 25,000 Per MEA GVEA - Douglas Substation OOS relaying and communications ---610 ------Per GVEA CEA - Telecomm Support (Douglas, Teeland, Anc-Fbks Leased Circuits)---31,403 2,125 --1,742 ---Per CEA Page 1 of 4 (59,839)203,283 200,060 169,971 123,214 337,502 512,828 424,043 196,472 514,200 481,000 FERC 571 - Maintenance of Overhead Lines GVEA - Northern Maintenance 29,056 50,631 30,102 42,580 147,299 37,171 68,204 107,641 44,048 100,000 150,000 Per GVEA GVEA-Private Line Telephone Service --------20,961 - GVEA - Northern ROW Clearing 29,852 13,209 -15,321 99,382 89,493 36,721 68,882 -300,000 550,000 Per GVEA GVEA - Landing Pads -------75,000 Per GVEA GVEA - Re-level Structures & Adjust Guys 46,710 ------80,000 Per GVEA GVEA - Repair Tower 504 Foundation --Per GVEA GVEA - Repair Tower 537 Foundation - GVEA - Repair Tower 539 Foundation - GVEA - Repair Tower 569 Foundation --Per GVEA GVEA - Repair Tower 531 Foundation 50,000 150,000 GVEA - Repair Tower 532 Foundation 50,000 150,000 GVEA - Repair Tower 748 ---486,740 677,877 ----Per GVEA GVEA - Repair Tower 692 --------Per GVEA MEA - Special Patrols [Incl Helicopter Inspections]12,594 ---4,571 599 488 10,000 -Per MEA MEA - Southern Maint (Incl Ground and Climbing Inspect)29,195 12,893 8,804 187,283 181,802 97,175 138,199 191,358 -140,000 140,000 Per MEA MEA - Southern ROW Clearing -8,382 509 39,184 76,703 38,023 228,413 168,367 170,150 500,000 500,000 Per MEA MEA - Southern ROW Remote Sensing and Analysis 125,000 MEA - TWR 195 Repair Monitoring --------Per MEA MEA - Equipment Repair and Replacement ----16,521 780,866 76,494 -684,000 350,000 Per MEA 147,407 85,115 39,415 771,108 1,187,634 278,383 1,252,403 613,341 235,647 1,834,000 2,270,000 FERC 924 - Property Insurance AK Intertie - Insurance 24,660 129,723 31,016 35,466 33,909 36,253 38,773 37,133 -25,000 - Per AEA (Gen Liab/Comm Umbrella) & MEA (incl Aviation) 24,660 129,723 31,016 35,466 33,909 36,253 38,773 37,133 -25,000 - Intertie Operating Costs Total 259,542 567,232 466,181 1,110,688 1,483,961 781,318 1,937,286 1,301,209 473,589 2,544,100 3,679,000 FERC 570 - Maintenance of Station Equipment MEA - Replace Protective Relay Schemes Douglas ---843,382 6,324 ------Per MEA ---843,382 6,324 ------ Intertie Cost of Improvements Total ---843,382 6,324 ------ FERC 920 - AEA Administrative Costs Personal Services, Travel and Other Costs 24,581 53,801 43,446 99,383 85,139 101,058 210,409 235,608 25,891 200,000 250,000 Per AEA 24,581 53,801 43,446 99,383 85,139 101,058 210,409 235,608 25,891 200,000 250,000 FERC 920 - IMC Administrative Costs IMC Administrative Costs (Audit, meetings, legal)12,097 34,598 62,326 22,364 18,211 11,533 30,890 29,276 16,466 20,000 -Per IMC Chair 12,097 34,598 62,326 22,364 18,211 11,533 30,890 29,276 16,466 20,000 - FERC 566 - Miscellaneous Transmission Expense Misc Studies: System Reserves Study (IBR), PSS/E maint, 230 kV Upgrade System Impact Study -173,055 140,218 15,680 20,719 69,023 186,675 145,327 (27,000)216,000 466,000 per IOC LIDAR study (complete lidar, vegetation, PLS CADD file with drawings, structure/foundation movement, infrared, and imaging)226,125 -- Asset management plan 50,000 -per IOC Proposed Synchrophaser system 230,000 -per IOC Unbalanced Snow Load mitigation analysis and recommendations 50,000 - Reliability Standards Update (Hdale Inc.)-86,213 ------per IOC -259,268 140,218 15,680 20,719 69,023 412,800 145,327 (27,000)546,000 466,000 Intertie Administration Costs Total 36,678 347,667 245,990 137,427 124,069 181,614 654,099 410,211 15,357 766,000 716,000 TOTAL EXPENSE 296,220 914,899 712,171 2,091,497 1,614,354 962,932 2,591,385 1,711,420 488,945 3,310,100 4,395,000 SURPLUS (SHORTAGE)2,485,428 2,801,530 1,003,208 669,285 835,007 1,552,729 214,267 1,044,468 1,020,133 194,885 280,238 Page 2 of 4 Alaska Intertie FY24 Approved Budget True up to Contract GVEA MEA CEA TOTAL USAGE CAPACITY ADMIN CASH FLOW MONTH Value MWH MWH MWH MWH GVEA MEA CEA GVEA MEA CEA GVEA | MEA | CEA TOTALS Jul 11,500 1,993 0 13,493 $140,530 $24,354 $0 $303,420 $88,692 $214,728 $59,667 $831,391 Aug 13,600 2,034 0 15,634 $166,192 $24,855 $0 $59,667 $250,714 Sep 14,050 1,972 0 16,022 $171,691 $24,098 $0 $59,667 $255,456 Oct 23,500 2,036 0 25,536 $287,170 $24,880 $0 $59,667 $371,717 Nov 25,190 2,273 0 27,463 $307,822 $27,776 $0 $59,667 $395,265 Dec 24,990 2,494 0 27,484 $305,378 $30,477 $0 $59,667 $395,521 Jan 25,470 2,495 0 27,965 $311,243 $30,489 $0 $59,667 $401,399 Feb 24,740 2,043 0 26,783 $302,323 $24,965 $0 $59,667 $386,955 Mar 21,230 2,158 0 23,388 $259,431 $26,371 $0 $59,667 $345,468 Apr 13,470 1,943 0 15,413 $164,603 $23,743 $0 $59,667 $248,014 May 20,380 1,871 0 22,251 $249,044 $22,864 $0 $59,667 $331,574 Jun 31,070 1,835 0 32,905 $379,675 $22,424 $0 $59,667 $461,766 TOTAL 0 249,190 25,147 0 274,337 $3,045,102 $307,296 $0 $303,420 $88,692 $214,728 $716,000 $4,675,238 Total Energy:$3,352,398 Total Capacity :$606,840 274,337 MWH 251,476 MWH 204,984 MWH TOTAL MWH REVENUE $4,675,238 O&M BUDGET - Operating 3,679,000 O&M BUDGET - Administrative 716,000 UTILITY FY 23 TOTAL O&M BUDGET 4,395,000 MEA 29.20% 22.80 MW SURPLUS (SHORTAGE)$280,238 CEA 70.80% 55.20 MW GVEA 100.00% 78.00 MW Annual Participant Administrative Contribution 238,666.67 156.0 Monthly Contribution per Participant 19,888.89 Usage Rate per KWH 0.01222$ Capacity Rate $3.89 Section 7.2.2 MINIMUM USAGE CONTRACT VALUE ALASKA INTERTIE FISCAL YEAR 2024 ENERGY PROJECTION TOTAL INTERTIE PROJECTED ENERGY USAGE Usage estimate reduced by 1/12 of Total for rate calculations Page 3 of 4 Alaska Intertie FY24 Approved Budget Annual System Demand 19-20 20-21 21-22 22-23 3 YR AVG. SOUTHERN UTILITY PARTICIPANTS (MW) CEA 364.5 366.0 349.8 343.8 353.2 MW DRAFT APPROVED APPROVED APPROVED APPROVED APPROVED MEA 137.0 145.0 146.0 147.0 146.0 MW 6/30/2024 6/30/2023 6/30/2022 6/30/2021 6/30/2020 6/30/2019 UNITS FY24 FY23 FY22 FY21 FY20 FY19 USAGE KWH 251,476,000 415,247,000 187,902,000 187,902,000 187,902,000 297,441,000 OPERATING BUDGET $3679000 2,544,100 1,992,890 2,007,385 2,168,391 2,024,298 MITCR KW 156000 156,000 156,100 156,000 156,000 156,000 TOTAL 499.2 MW ENERGY (A)$.000/KWH $0.01222 $0.00512 $0.00886 $0.00892 $0.00964 $0.00568 NORTHERN UTILITY PARTICIPANTS (MW) CAPACITY (B)$/KW $3.89 $2.69 $2.11 $2.12 $2.29 $2.14 GVEA 191 204 204.7 205.5 204.7 MW TOTAL 204.7 MW MITCR DETERMINATION FY 24 KWH CAP RATE CAP CHARGES MEA 29.20%22.80 MW 22,800 $3.89 88,692.00 CEA 70.80%55.20 MW 55,200 $3.89 214,728.00 GVEA 100.00%78.00 MW 78,000 $3.89 303,420.00 156.00 MW 156,000 606,840.00 (A) See Section 7.2.5 AK Intertie Agreement (B) See Section 7.2.6 AK Intertie Agreement MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS (MITCR) DETERMINATION FOR FISCAL YEAR 2024 Page 4 of 4 Page 1 of 13 March 2, 2023 To: Jon Sinclair, Chair of Intertie Operating Committee From: Keith Palchikoff, Chair of System Studies Subcommittee Re: Recommendation to Approve One Year Contract with EPG for Railbelt Synchrophasor System and Budget Funding for a Second Year Summary: The System Studies Subcommittee, including HEA, recommends the IOC approve GVEA contracting with EPG for a turnkey, one year, Railbelt synchrophasor pilot project to commence by April 1 and be commissioned by August 31. The cost of the EPG contract is $250k, 9% over the $230k allotted in the current fiscal year IMC budget. In addition, the SSS recommends budgeting $280k to renew the EPG contract for a second year which will also expand data collection to an additional 10 substations. The project will require assistance from other IOC subcommittees. The IOC should consider assigning the relay, SCADA and operations subcommittees to assist or engage with their respective SSS participants from each utility. The full contract is contained herein as Attachment 4. Background: In 2021, to improve the ongoing Railbelt oscillation remediation effort, the SSS developed a pilot plan for a communal system to stream, store and analyze synchrophasor data from Tesla high speed data recorders (DFR) at 12 key Railbelt substations. The data recorders are part of network of approximately $2 million of underutilized recorders installed at 45 transmission substations from Delta Junction to Homer. For the past 20 years regional synchrophasor data networks have successfully been used throughout the Lower 48 transmission grid for oscillation detection, source location and overall awareness of transmission system stability. CEA uses synchrophasor data to monitor areas of the South Central transmission network. In early 2022, the SSS contacted vendors and requested budgetary pricing and availability of cloud based software services that would communicate with the Railbelt data recorders. Based on the vendor responses and a project justification memorandum, a budget amount was approved in the IMC budget for the current fiscal year. In October, 2022 the SSS, through GVEA, issued a formal request for proposals for a cloud based synchrophasor system and then promoted the RFP during a public presentation at the November NWPPA E&O Conference in Anchorage. The full contract is provided alongside this memo as a separate document. Page 2 of 13 Synchrophasor systems with interconnected PMUs are widely used throughout North America and industrialized countries with managed transmission networks. These outdated maps show the Lower 48 grid during the previous decade. The systems have since expanded. The Railbelt Synchrophasor Project will modernize the Alaska transmission network. The SSS received four proposals and in late December selected Pasadena, California based Electric Power Group (EPG). In January, EPG presented their proposal to an audience of Railbelt technical personnel from HEA, CEA, MEA, GVEA and AEA. On behalf of the IMC, GVEA purchasing department worked with EPG and the SSS to draft a proposed contract (see Attachment 1) for a turnkey, annual subscription service. 2014 Page 3 of 13 Project Cost, Justification and Return on Investment: The EPG system is a software as a service (SAaS) annual subscription consisting of both local software installed at each Railbelt utility and a communal cloud software system hosted in a high security data center. The EPG turnkey contract pricing is summarized in the first row of Table 1 below and with more detail in Attachment 1. This price includes initial setup costs and training. The pricing in Table 1 is for single year commitments and includes optional annual escalators to increase the number of connected substations from the initial 12 to a possible 50 by year 5.1 Attachment 1 lists price reductions for multi- year commitments and an additional reduction if pre-paying for multiple years. The project is estimated to provide a positive return on investment which increases over time. Table 1 summarizes the annual return on investment over five years and Attachment 2 lists the details of how the total benefit was calculated. The key benefits are improvements in transmission / Intertie loading, mitigating risk of equipment damage due to power system oscillations, reduction in cost to comply with reliability standards, more accurate system models for planning Railbelt capital projects / renewable integration and optimizing Railbelt reserves commitments. The software subscription renews each year in April and there is no penalty for cancellation. The April contract renewal date was set to integrate with the budget planning schedule of the IMC and individual utilities. Table 1 *Details for Net Benefits calculation are shown in Attachment 2 In addition to the EPG contract cost, each of the four Railbelt utilities would need an on premise computer for aggregating the data from the Tesla recorders installed at their respective substations, a secure Internet connection to the synchrophasor cloud system and internal support labor for the initial setup. Project Schedule and Utility Labor Contribution: The proposed schedule is listed below in Table 2 and has been reviewed by relevant staff at each utility. As a turnkey project, the bulk of the work will be performed by EPG. Each utility will need to allocate 28 to 40 hours of IT labor to implement the on premise portion (refer to Attachment 3 for breakdown on hours). In addition there would be additional labor expected from a project manager at each utility, for 1 Increasing the number of connected substations will extend the Railbelt coverage to allow a full network model solution within the linear state estimator and ensure each power plant interconnection is measured, allowing for complete model validations and more accurate location of oscillation sources. Row#Description Year 1 FY 2023 Pilot Year 2 Year 3 Year 4 Year 5 1 EPG Contract Annual Subscription 250,000$ 265,000$ 265,000$ 300,000$ 315,000$ 2 Expanded Substation Coverage (optional) -$ 15,000$ 25,000$ 40,000$ 40,000$ 3 Total Railbelt Shared Costs (Rows 1 and 2)250,000$ 280,000$ 290,000$ 340,000$ 355,000$ 4 Number of Connected Substations 12 22 32 45 50 5 Total Benefits - High Estimate 9,288,000$ 9,288,000$ 9,288,000$ 9,288,000$ 9,288,000$ 6 Total Benefits - Low Estimate 309,600$ 371,520$ 422,182$ 516,000$ 546,353$ 7 Net Benefits Low Estimate*59,600$ 106,520$ 157,182$ 216,000$ 231,353$ 8 ROI = Net Benefits / Total Costs 24%40%59%72%73% 9 Five year average Return on Investment - Railbelt Synchrophasor System 54% Page 4 of 13 operator and engineering staff to attend training and for ongoing testing / commissioning feedback to EPG during the initial setup. GVEA, HEA and CEA staff reviewed the schedule and support the timeline. Due to IT labor constraints and the need to reconfigure their datalinks to DGS and EGS, MEA expects to complete their part of the project later in the year. To keep the project schedule on track, the SSS is investigating an option for either CEA or GVEA to connect via existing DGS datalinks to the AEA owned Tesla data recorder at DGS. The SSS recommends the IOC assign other subcommittees to assist with the project, including SCADA and Telecommunications (substation datalinks and possible ICCP data integration), Engineering, Relay and Reliability (involvement with Tesla recorders) and Dispatch and System Operations (Control room integration). Table 2 Example Key Performance Indicators for Measuring Project Benefits Following commissioning, a recurring KPI report will quantify the system value. Improvement to Railbelt Real Time Operation 1. Synchrophasor system availability / up time – how reliable is the software system 2. Number of Railbelt disturbance events captured, reported to designated recipients within xx minutes with root cause analysis 3. Number of Railbelt stability / oscillation alarms reported and acted upon by system dispatchers. 4. Number of Railbelt oscillation sources detected. 5. Changes to Alaska Intertie capacity utilization due to real time stability reporting 6. Changes to Railbelt spinning reserve requirements due to inertia calculation Improvements to Railbelt Engineering and Reliability Analysis 1. Number of PSS/E model checks and corrections 2. Number of Railbelt reliability standard compliance efforts – e.g. machine model validation reports / updated performed 3. Complete a Railbelt oscillation analysis report once per year, more often if needed, with recommendations for any improvements. 4. Complete a Railbelt reserves performance analysis, inertia analysis with options for adjusting / optimizing reserve requirements. Page 5 of 13 Attachment 1 SYNCHROPHASOR SOLUTION SUBSCRIPTION FEES The Synchrophasor Solution consists of the Cloud Solution and Local Solution. The Subscription Fees include access to the Software listed in Exhibit A for each the Cloud and Local Solution and the Provision of Services described in Section 2 and Section 3 of this Agreement for the Cloud and Local Solution, respectively. The following items detail the Subscription Fees for the Initial Term, the Renewal options for continuing with the Subscription upon expiration of the Initial Term, and the fees associated with adding PMUs to the Synchrophasor Solution above the initial 12 PMUs. Initial Term: Synchrophasor Solution Deployment and Subscription Term through March 31, 2024 Commencement Date: April 1, 2023 Subscription Term: Valid through March 31, 2024 Start-up Professional Services Included Training Services Included Project Management Services Included Acceptance Testing Included Payment Milestones Milestone Target Date Payment Commencement Date 4/1/23 $150,000 Synchrophasor Solution Operational 6/30/23 $75,000 Official Go Live 8/31/23 $25,000 Payment Term NET 30 Note: System Availability commitment for the Cloud Solution will be applicable starting from the official go-live date noted in Exhibit B of this Agreement. Subscription Continuation: As per Clause 10.3 of this Agreement, the Subscription will automatically renew for a 12 -month period unless cancelled in writing at least 90 days prior the completion of the prior Subscription Term. The 12- month, annual Subscription Terms and associated Subscription Fees through March 31, 2028 is shown below. Subscription Term 4/1/24 – 3/31/25 4/1/25 – 3/31/26 4/1/26 – 3/31/27 4/1/27 – 3/31/28 Subscription Fee $265,000 $265,000 $300,000 $315,000 Payment Payable 4/1/24 4/1/25 4/1/26 4/1/27 Payment Term NET 30 NET 30 NET 30 NET 30 Customer Option for a Multi-year Subscription Customer will have the option to procure a multi-year Subscription for the period of April 1, 2024 – March 31, 2028 at a discounted price as shown below. Such procurement shall take place at least 90 days prior to the completion of the Initial Term. Page 6 of 13 Master Services Agreement Golden Valley Electric Association (GVEA) and Electric Power Group, LLC Subscription Term 4/1/24 – 3/31/28 Subscription Fee $1,060,000 Payment Schedule 4/1/24 $250,000 4/1/25 $260,000 4/1/26 $270,000 4/1/27 $280,000 Payment Term NET 30 Note: Each payment corresponds to the subsequent 12-month period (e.g. 4/1/24 payment for 4/1/24 – 3/31/25). Any unpaid contract term can be terminated with the payment of a one-time termination fee of $75,000. Customer Option for a Multi-year Subscription with a Pre-payment Discount If Customer elects to procure a multi-year option, an additional discount is available for pre-payment of the contract as shown below. Subscription Term 4/1/24 – 3/31/28 Subscription Fee $1,060,000 (-) Pre-pay Discount ($60,000) Final Subscription Fee $1,000,000 Payable 4/1/24 Payment Term NET 30 Note: Pre-paid Subscription Fees are non-refundable. Subscription Fees for Optional Software for the Local Solution The Subscription Fees provided above are based on the Software listed in Exhibit A. Additional Software for PI and ICCP interfaces is available for use with the Local Solution to members of the Alaska Railbelt either individually or all members of the Alaska Railbelt. Annual Subscription Fees for each of the additional software has been provide below and will be incremental to the annual Subscription Fees noted in the prior sections. Optional Software for Local Solution Per Member Annual Subscription Fee All Alaska Railbelt Members Annual Subscription Fee Interface for OSI PI historian $4,000 $16,000 Interface for OSII Monarch SCADA / EMS $4,000 $16,000 Interface for ICCP data exchange to third party system $4,000 $16,000 Subscription Fees noted above are annual and for the first year. All other terms and conditions of this Agreement will apply to the optional software, including renewal terms. Subscription Fees will include EPG support for initial installation and commissioning of the additional Software with each Local Solution. After initial commissioning, Support Services described in Exhibit D will apply provided optional software remains under a valid Subscription Term. Page 7 of 13 Master Services Agreement Golden Valley Electric Association (GVEA) and Electric Power Group, LLC Incremental Cost for Additional PMUs The Subscription to the Synchrophasor Solution will initially be based on usage with up to 12 PMUs total. The Subscription Fees noted in the prior to sections of this Exhibit E are based on 12 PMUs total. The Customer will have the following options available to add additional PMUs to the Synchrophasor Solution beyond the initial 12: Total Incremental Annual Subscription Fee (1) Number of Additional PMUs (2) Cost Per Added PMU per Year a) Pay as you Go $1,500 (3) 1 $1,500 b) Bundle of 20 $25,000 20 $1,250 c) Bundle of 40 $40,000 40 $1,000 Notes: 1) Noted Total Incremental Annual Subscription Fee is in addition to the Subscription Fee per year note in the prior two sections of this Exhibit E. 2) Represents the total number of additional PMUs above the initial 12 PMUs. 3) Consists of $1,000 per year for the Cloud Solution and $500 per year for the Local Solution. Page 8 of 13 Attachment 2 – Breakdown of System Benefits Below are three categories of benefits and estimated annual dollar values. The combined estimate of $9,288,000 is the high amount shown in Table 1 above. To compute a more conservative estimate of return on investment, the low estimate in Table 1 was reduced by at least one order magnitude. 1. Dispatch Center Real Time Applications = $3,752,000 per year consisting of average of $938,000 per year per utility in machine damage risk mitigation, Intertie loading improvements, Railbelt reliability improvements and optimization of unit commitment. Not all categories below have a dollar value assigned. 1.1 Oscillation detection - $1,000,000 - new capability to rapidly detect and respond to unstable or machine damaging oscillations. Railbelt EMS / SCADA systems do not perform oscillation detection, source location or modal analysis. In the recent past, the Railbelt has experienced unstable oscillations resulting in wide spread load shed and possible machine damage from subsynchronous torsional interaction (SSTI) to synchronous generators.2 The Railbelt has invested hundreds of thousands of dollars to understand the type, extent, source and remediation options and does not yet have a coordinated and real-time system to notify system operators. Increased penetration of inverter based resources is known to increase oscillations.3 1.2 Transmission line capacity and stability improvements – $2,628,000 – a new capability that will provide accurate transmission line loading for prevailing conditions by measuring the phase angle difference across the line segments. Current Alaska Intertie loading limits are static values based on infrequent studies using simulations based on imperfect software models. Additionally, the ability to monitor the angle difference across the interconnections should facilitate faster restoration following an islanding event. 1.3 Frequency event detection - Improvement to an existing capability. Railbelt dispatch centers have real-time capability to detect and measure absolute frequency excursions. However, the measurement methods / capabilities / fidelity are inconsistent between utilities and limited in geographic scope. The limited scope results in lack of visibility during islanding situations. In addition, the frequency measurements may not be integrated into the EMS for convenient access. The synchrophasor system offers both coordinated and consistent absolute frequency and rate-of-change of frequency measurements from key locations across the Railbelt with the option to use ICCP to stream the measurement data and alerts to the EMS. 1.4 Voltage stability monitoring – A new capability not available within the EMS / SCADA systems. Many of the unstable contingencies simulated for the Alaska Intertie are due to voltage collapse. The Alaska Intertie operating procedure calls for taking the Intertie out of service if two of the three AEA SVCs are offline. This requirement is based on system studies. It is unclear if this is an actual requirement and a synchrophasor system with empirical data would allow keeping the Intertie in service, monitoring the voltage stability and reducing the loading as needed. 2 and 3 References provided on page 11 Page 9 of 13 1.5 Event Detection, management, alarming and restoration – $100,000 reduction in Railbelt transmission system outage time. Improve existing capability by expanding and coordinating dispatch centers' awareness / validation / diagnosis of critical events throughout the Railbelt where operators can manually intervene and take action. Local events may start in one control area and then propagate and impact other areas. The synchrophasor system will detect events throughout the Railbelt and deliver a consistent set of alerts to all dispatch centers. The alerts can be integrated with the EMS via ICCP. 1.6 Wide area awareness/visibility Improvement / expand each dispatch center’s awareness of overall steady state of the Railbelt. 1.7 Renewable resource integration performance monitoring - New Capability. Due to the 3 to 5 second measurement scan rate, Railbelt EMS / SCADA systems lack the fidelity to record and display the fast dynamics of inverter based resources. Standard and specialized synchrophasor data is recorded at high sampling rates. 1.8 Immediate Access to Disturbance Reports – $24,000 - dispatch and management do not have to contact engineer to download, review and summarize Improvement Consistent, unified, timely, detailed and insightful reporting of Railbelt disturbances. The current reporting system does not provide these capabilities. A likely labor savings of 5 hours / month per utility or 240 hours annually @ $100/hr. = $24,000 labor savings. 1.9 Inertia Calculation / Reserves Optimization – value captured in the next group below - new Capability - Railbelt EMS / SCADA systems do not perform inertia calculation and calculated estimates using models and simulations are not timely and may not capture actual system dynamics such as effect of system load characteristics. Following a system disturbance, the synchrophasor system will compute and report the system inertia. This could allow optimization of contingency reserve requirements, potentially freeing BESS capacity for other uses or reducing reserves carried on rotating machines. Next iteration of EPG inertia calculation will compute during steady state operation to facilitate real-time optimization of dispatchable reserves. 2 - Study Mode Application = $5,436,000.00 per year or $1,359,000 average cost savings per utility per year. 2.1 Regulatory / Reliability / IBR Plant Interconnection Compliance – $48,000. Utility labor savings 10 hr. /month x 4 utilities @$100 hr. labor rate. Documenting compliance with various reliability standards where higher frequency data is needed and not available for SCADA - e.g. compliance / validation of the fast frequency response of each machine or validation of IBR plant interconnection voltage / frequency ride through performance. The labor savings would also apply where Railbelt wide coordinated reporting can utilize a Raibelt wide dataset and reporting format. This will allow all Railbelt entities to confirm grid operation performance by referencing a communal dataset. 2.2 Black Start / Contingency Response Training – Future value TBD - Use by dispatch centers to simulate and train for how to respond to large Railbelt outages. EPG offers a Page 10 of 13 simulator software add-on module that would facilitate communal training exercises. 2.3 Transmission system model validation & improvement – $200,000. Railbelt planning studies underpin multi-million dollar capital investments. These studies rely on the Railbelt PSS/E software model. Due to the importance of the model, Railbelt reliability standards AKMOD 32 and 33 require a structured process for model validation. The SSS, whose primary function is to maintain a validated Railbelt model, has struggled to fulfill this responsibility. In 2021, PTI, the PSS/E software vendor, provided a quote for $200,000 to perform a one-time validation / calibration effort. The work was deferred. Since the model is periodically updated to reflect changes to Railbelt infrastructure, the validation / calibration process needs to be a recurring activity to accommodate these changes and the EPG software will provide this structured process. 2.4 Power plant machine model improvement - $600,000. Validation / calibration of each of the individual power plant / machine models within the overall PSS/E model is a separate task and the focus of AKMOD-25, 26 and 27. The conservative cost to validate a 50 MW gas turbine machine model is $120,000 consisting of $60k for outside engineering services and $60k to take the machine out of normal service and operate if for a day of testing. Due to scheduling challenges and cost, often these models are infrequently validated and some Railbelt machines may not have been tested for many years. Assume model maintenance for 50 Railbelt machines, at five machines per year @ $120,000 per machine. 2.5 Post event analysis and forensics - $108,000 (utility labor savings 10 hr. /month x 4 utilities) + oscillation event analysis x 2 events per year (Historic cost for PTI study) 2.6 Operator training – dollar value TBD. Synchrophasor system includes a disturbance event playback mode to facilitate ongoing operation training and analysis of event response. 2.7 Fault Location – dollar value TBD. Additional capability of synchrophasor system not yet quantified. 2.8 Asset Monitoring – dollar value TBD. EPG offers a supplemental software module for early detection of failing of high voltage substation current and voltage transducers. Future value. 2.9 Engineering Labor Savings – dollar value TBD. System will provide easy access to Railbelt performance data to assist utility engineers and outside consultants with recurring study and analysis 2.10 Oscillation Mitigation Planning – $100,000. Annual system wide oscillation analysis (PTI / EPS single study cost). If the IMC elected to perform an annual analysis of Railbelt oscillation modes and damping to check impact of system changes, an annual study by a consulting group would be required. This synchrophasor system software would substitute for the consulting study report. 2.11 Inertia Calculation / Reserves Optimization – $4,380,000. Reduce BESS spin allocation 5 MW x 8760 hr. /year x $100 MWh avoided cost. Assumption is the overall Railbelt spin requirement will be optimized in aggregate by 5 MW based on analysis of inertia versus spin Page 11 of 13 events. The spin set points for two and eventually three Railbelt BESS systems could be dynamically adjusted based on actual inertia, freeing up BESS capacity for renewable regulation. 3 - Soft Benefits = $100,000 per year, average of $25k cost savings per utility per year 3.1 Improved Railbelt Utility Coordination - RRC Vision and Objective – dollar value = $50,000 per year or average $12.5k savings per year per utility due to coordinated operation - presenting each utility control center with consistent and identical views of the Railbelt network can facilitate pooling of operator experience, skills and intellect. Similar to a Railbelt power pooling arrangement, grid operation pooling via a common software framework should encourage operational efficiency and spur discussion for improvements / innovation. 3.2 Grid Modernization - Adopting Industry Standard Technology and Practices, Improving Workforce Development – $50,000. Two areas for cost savings and operational efficiency - 1) $12.5k per utility in reduced consulting labor costs due to new software tools that perform and present analysis that previously the Railbelt would pay a consultant to perform; 2) Consultants will also have access to the software tools and large data set which should improve efficiency and lower cost of study work while also allowing for new areas of analysis. References 1. Inverter-Based Resources (IBR) contribution to transmission system oscillations: a. IEEE Std 2800-2022, Standard for Interconnection and Interoperability of Inverter-Based Resources Interconnecting with Associated Transmission Electric Power Systems, page 131, subsection C.3.1.2 Control instability and section C3.2 Subsynchronous instability - pages 133 – 135. b. Integrating Inverter-Based Resources into Low Short Circuit Strength System, NERC Reliability Guideline, December 2017, page 8 c. NERC Reliability Guideline BPS-Connected Inverter-Based Resource Performance, September 2018, Chapter 7: Other Topics for Consideration, page 63 2. Using synchrophasor systems for model calibration a. “Multifold insights for power system dynamics from data assimilation: Meeting current challenges,” IEEE Power Energy Mag., vol. 21, no. 1, pp.36-43, Jan./Feb. 2023 3. Synchrophasor systems in North America a. Department of Energy, Office of Electricity – https://www.energy.gov/oe/big-data-synchrophasor-analysis 4. Subsynchronous Torsional Oscillations (SST) and Equipment Damage IEEE Subsynchronous Resonance Working Group of the Power System Dynamic Performance Subcommittee, “Reader’s Guide to Subsynchronous Resonance,” IEEE Transactions on Power Systems, vol. 7, no. 1, pp. 150–157, Feb. 1992, doi: 10.1109/59.141698. Page 12 of 13 Attachment 3 – Parts, Data Circuit and Labor Contribution per Utility Parts: Computers: 1) One Windows server at each utility for PDC and local visualization software, database and backup data storage. System admins will need remote desktop access. End users of the local visualization application connect via thin client web browser: A virtual server is acceptable for connection of up to 15 PMUs. 2) One Windows workstation or server for Generator Model Validation and PSS/E software. GMV is a desktop application and users will need desktop access to use the application. Spec. from GMV software manual: Minimum Data circuit requirements: a. Each PMU will have a minimum of two sets of three phase Voltage (A, B, C) - Six Phasors b. Each PMU will have a minimum of two sets of three phase Current (A, B, C) - Six Phasors c. Each PMU will have a minimum of frequency and rate of change of frequency – Two Phasors d. Total minimum number of phasors for each PMU will be 14. e. Each PMU will send data at 60 Samples per Second f. Required capacity for one PMU as described above is 104.2 kbps g. Required capacity for 4 PMUs from the local PDC to the Cloud solution is 416.4 kbps Page 13 of 13 Network equipment: Edge firewall or VPN appliance for IPsec tunnel to cloud system – each utility should already have this capability. Labor: The work effort ranges as each organization addresses these types of tasks differently. Below is an estimate of the number of people typically involved and the expected effort in hours. 1) Project management – one PM per utility 2) Per utility implementation labor – below estimate from EPG 3) Utility support for testing / commissioning Task EPG Role Customer Role Customer Required Resource Customer Effort Per Person (in Hours) Review and Order Hardware if required EPG will provide Hardware Requirements Customer will lead this effort One IT Admin One Procurement 4 hours Configure Network / Firewall Rules for PMU Input, and Output to Cloud over VPN EPG will advise and assist with requirements Customer will lead this effort One Network Admin 24 - 40 hours Installation of EPG Software EPG will lead this effort Customer will support One IT Admin 2 hours Configuration of EPG’s software for PMU Input and output to Cloud EPG will lead this effort Customer will support One IT Admin 4 - 8 hours Troubleshooting hardware and network issues EPG will support this effort Customer will lead this effort One IT Admin One Network Admin 8 hours The table above does not include training, which will require resources as each utility sees fit.